A method and system for detecting the performance of a horizontal gas well foam drainage agent

Abstract

The present application relates to the technical field of performance testing of foam drainage agents in horizontal gas wells, and specifically to a method and system for testing the performance of foam drainage agents in horizontal gas wells. The method comprises: obtaining historical foam drainage agent-related test data and test data of the foam drainage agent in the current horizontal gas well; performing a comparative analysis of the complex well conditions of the current horizontal gas well and all historical gas wells; and forward-fusing the analysis results with the downhole environmental similarity between the current horizontal gas well and each historical gas well, and correcting the difference in gas well liquid carrying capacity between the current horizontal gas well and each historical gas well to determine the actual liquid carrying performance of the foam drainage agent in the current horizontal gas well, thereby determining the foam drainage agent performance test results of the current horizontal gas well. The present application aims to avoid excessive interference in the performance testing of foam drainage agents in horizontal gas wells caused by excessively complex well conditions and extreme downhole environmental influences in horizontal gas wells.

Description

Technical Field

[0001] The present application relates to the technical field of performance detection of foam drainage agents for horizontal gas wells, and in particular to a method and system for detecting the performance of foam drainage agents for horizontal gas wells. Background Art

[0002] Horizontal gas well foam dewatering agents are surfactant-based chemical agents primarily used to address production decline caused by bottomhole liquid accumulation during the middle and late stages of gas well development. Their core function is to reduce gas-liquid interfacial tension, forming a stable, low-density foam. This foam, with the help of airflow, carries the bottomhole liquid to the surface, thereby restoring or increasing gas well production. However, horizontal gas wells are long and have high inclination angles, making liquid more susceptible to stagnation. Traditional dewatering methods such as pumping and gas lift are inefficient and costly in horizontal wells. Foam dewatering agents, through their physical and chemical synergy, offer a cost-effective solution.

[0003] The performance evaluation of current foam drainage agents has the following defects:

[0004] (1) When testing the performance of foam drainage agents in horizontal gas wells, the traditional method is to detect relevant data downhole without considering the impact of the complexity of the horizontal gas well during the testing process. Chinese patent CN119044419B, a method and system for testing the drainage performance of foam drainage agents, solves the problem that the existing testing of the drainage performance of foam drainage agents does not fully consider the impact of temperature and pressure fluctuations on foam, and cannot ensure that the prerequisites for testing are fully met. Temperature and pressure have a great impact on the performance of foam.

[0005] Although the performance testing system for foam drainage agents has been gradually improved, horizontal gas wells currently face more extreme environmental complexities, such as high temperature, high salinity, high condensate content, and ultra-deep well pressure. The abstract of the paper "Development of Foam Drainage Agents and Research on Drainage Processes in Extreme Environments" explains that the actual foam drainage effect is affected by many factors, such as high temperature, salinity, condensate content, and methanol content.

[0006] (2) Background technology of the method for evaluating the performance of foam drainage agents in horizontal gas wells in Chinese patent CN107422084B. Article 3 states that existing methods are all proposed for vertical wells, without considering the impact of the inclined section and horizontal section of the horizontal well on foam generation. In particular, due to the special wellbore structure, flow characteristics and environmental conditions of horizontal gas wells, the application process of foam drainage agents faces more complex challenges than other types of gas wells such as vertical wells and directional wells, which may cause significant interference with the performance test results of the foam drainage agents. Summary of the Invention

[0007] In order to solve the above technical problems, this application provides a method and system for detecting the performance of a horizontal gas well foam dewatering agent. The technical solutions adopted are as follows:

[0008] In a first aspect, an embodiment of the present application provides a method for detecting the performance of a horizontal gas well foam drainage agent, the method comprising the following steps:

[0009] Obtain historical foam drainage agent related test data and current horizontal gas well foam drainage agent test data;

[0010] Conducting comparative analysis of complex well conditions between current horizontal gas wells and all historical gas wells, including comparative analysis of complex well conditions based on the same gas well type and based on different gas well types;

[0011] The results of the complex well condition comparison analysis are forward-fused with the downhole environment similarity between the current horizontal gas well and each historical gas well to determine the comprehensive similarity between the environment and well conditions of the current horizontal gas well and each historical gas well.

[0012] The difference in liquid carrying capacity between the current horizontal gas well and each historical gas well is corrected using the comprehensive similarity of the environment and well conditions. The correction results of all historical gas wells are combined to determine the actual liquid carrying performance of the foam drainage agent in the current horizontal gas well.

[0013] The actual liquid carrying performance is used to determine the performance test results of the foam dewatering agent in the current horizontal gas well.

[0014] Preferably, the comparative analysis of complex well conditions based on the same gas well type includes:

[0015] Obtain the extension distance and inclination of the build-up section of the current horizontal gas well and each historical horizontal gas well;

[0016] Calculate the similarity of the extension distance and the inclination of the build-up section between the current horizontal gas well and each historical horizontal gas well;

[0017] The similarity of extension distance and the similarity of build-up section inclination are forward fused to determine the basic scale similarity between the current horizontal gas well and each historical horizontal gas well.

[0018] Preferably, the comparative analysis of complex well conditions based on different gas well types includes:

[0019] Analyze the proximity of the current horizontal gas well build-up section inclination to 50 degrees;

[0020] respectively obtaining the critical flow velocities of the current horizontal gas well in the build-up section, the vertical section, and the horizontal section, and combining the proximity to determine the comprehensive critical flow velocity of the current horizontal gas well;

[0021] The difference between the comprehensive critical flow velocity of the current horizontal gas well and the critical flow velocity of each historical vertical well is used to determine the similarity of the flow pattern between the current horizontal gas well and each historical vertical well.

[0022] Preferably, the method of determining the foam drainage agent performance test result of the current horizontal gas well by using the actual liquid carrying performance includes:

[0023] When the actual liquid carrying performance of the foam drainage agent of the current horizontal gas well is greater than or equal to the preset actual liquid carrying performance threshold, the performance of the foam drainage agent of the current horizontal gas well is qualified; otherwise, the performance of the foam drainage agent of the current horizontal gas well is unqualified.

[0024] Preferably, the calculation of the similarity of the extension distance and the similarity of the inclination of the build-up section between the current horizontal gas well and each of the historical horizontal gas wells includes:

[0025] Compare the minimum and maximum extension distances of the current horizontal gas well with those of each historical horizontal gas well to determine the similarity of the extension distances;

[0026] The minimum and maximum values of the build-up section inclinations of the current horizontal gas well and each historical horizontal gas well are compared to determine the similarity of the build-up section inclinations.

[0027] Preferably, the method for determining the comprehensive critical flow velocity of the current horizontal gas well includes:

[0028] The result of multiplying the proximity of the current horizontal gas well by the critical flow velocity of the deflection section in the current horizontal gas well is recorded as a first product;

[0029] and multiplying the absolute value of the difference between the proximity of the current horizontal gas well and the value 1 by the average critical velocity of the vertical section and the horizontal section of the current horizontal gas well, recording the result as the second product;

[0030] The first product and the second product are added together to determine the comprehensive critical flow rate of the current horizontal gas well.

[0031] Preferably, the method for obtaining the downhole environment similarity between the current horizontal gas well and each historical gas well includes:

[0032] For each downhole environmental data, calculate the ratio of the element value of the current horizontal gas well to that of each historical gas well under the environmental data;

[0033] The ratios of all environmental data are comprehensively processed to obtain the downhole environmental similarity between the current horizontal gas well and each historical gas well.

[0034] Preferably, the method for determining the similarity of the flow pattern between the current horizontal gas well and each historical vertical well includes:

[0035] For the mth vertical well in history, the comprehensive critical flow velocity of the current horizontal gas well is subtracted from the critical flow velocity of the mth vertical well in history, and inverse normalization is performed to determine the similarity of the flow pattern between the current horizontal gas well and the mth vertical well in history.

[0036] Preferably, the acquisition of historical foam drainage agent related test data and current horizontal gas well foam drainage agent test data includes:

[0037] The historical foam drainage agent related detection data includes related detection data of multiple horizontal gas wells and multiple vertical wells;

[0038] The relevant detection data and test data include: gas well data, gas well production data, downhole environment data, and application effect of foam drainage agent;

[0039] Among them, gas well data includes: extension distance, inclination of the inclination section and critical flow rate; downhole environmental data includes: downhole pressure, temperature, salinity and condensate oil content; the application effect of foam drainage agent includes: liquid carrying capacity.

[0040] In the second aspect, another embodiment of the present application also provides a system for detecting the performance of a horizontal gas well foam drainage agent, comprising a memory, a processor, and a computer program stored in the memory and running on the processor, wherein when the processor executes the computer program, it implements any one of the above-mentioned methods for detecting the performance of a horizontal gas well foam drainage agent.

[0041] This application has at least the following beneficial effects:

[0042] Based on what is described in this application, this application can conduct a comparative analysis of complex well conditions between the current horizontal gas well and historical gas wells of the same type and different types, and consider the similarity of downhole environmental data. Based on the liquid carrying performance of the foam drainage agent, the actual liquid carrying performance of the current horizontal gas well can be determined according to the comprehensive similarity of the environment and well conditions between the current horizontal gas well and each historical gas well, thereby completing the performance test of the foam drainage agent for the horizontal gas well. This operation avoids excessive interference in the performance test of the foam drainage agent for the horizontal gas well caused by the excessively complex well conditions and extreme downhole environmental influences of the horizontal gas well. BRIEF DESCRIPTION OF THE DRAWINGS

[0043] In order to more clearly illustrate the technical solutions and advantages of the embodiments of the present application or the prior art, the following is a brief introduction to the drawings required for use in the embodiments or the description of the prior art. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without any creative work.

[0044] Figure 1A flow chart of a method for testing the performance of a horizontal gas well foam drainage agent provided in one embodiment of the present application;

[0045] Figure 2 A flowchart of the analysis process for detecting the performance of a foam drainage agent in a current horizontal gas well is provided in accordance with one embodiment of the present application. DETAILED DESCRIPTION

[0046] One embodiment of the present application provides a method for detecting the performance of a horizontal gas well foam drainage agent. Figure 1 , the method comprises the following steps:

[0047] Obtain historical foam drainage agent related test data and current horizontal gas well foam drainage agent test data;

[0048] Conducting comparative analysis of complex well conditions between current horizontal gas wells and all historical gas wells, including comparative analysis of complex well conditions based on the same gas well type and based on different gas well types;

[0049] The results of the complex well condition comparison analysis are forward-fused with the downhole environment similarity between the current horizontal gas well and each historical gas well to determine the comprehensive similarity between the environment and well conditions of the current horizontal gas well and each historical gas well.

[0050] The difference in liquid carrying capacity between the current horizontal gas well and each historical gas well is corrected using the comprehensive similarity of the environment and well conditions. The correction results of all historical gas wells are combined to determine the actual liquid carrying performance of the foam drainage agent in the current horizontal gas well.

[0051] The actual liquid carrying performance is used to determine the performance test results of the foam dewatering agent in the current horizontal gas well.

[0052] Among them, this application specifically analyzes the process of the above steps. The analysis process flow chart of the current horizontal gas well foam drainage agent performance test is shown in the attached Figure 2 As shown, specifically:

[0053] S001: Obtain historical foam drainage agent related test data and current horizontal gas well foam drainage agent test data.

[0054] In the middle and late stages of gas well production, formation pressure decreases, and the gas flow rate is insufficient to carry bottomhole liquids (such as formation water and condensate), resulting in liquid accumulation, increased backpressure, and a sudden drop in production. Therefore, the use of foam dewatering agents can create low-density foam and, with the help of airflow, carry the bottomhole liquid to the surface, thereby restoring or increasing gas well production.

[0055] Throughout the entire process, the performance of the foam dewatering agent will be fully tested due to the complex factors within the gas well and the differences in characteristics of different types of gas wells.

[0056] Therefore, the relevant test data of the historical treatments performed by the foam drainage agent and the test data of the current horizontal gas well foam drainage agent are obtained here to facilitate subsequent treatment.

[0057] The historical foam drainage agent related detection data includes related detection data of multiple horizontal gas wells and multiple vertical wells; the related detection data and test data both include: gas well data, gas well production data, downhole environment data, and application effects of foam drainage agents.

[0058] Among them, gas well data includes: extension distance, inclination of the inclination section and critical flow rate; downhole environmental data includes: downhole pressure, temperature, salinity and condensate oil content; the application effect of foam drainage agent includes: liquid carrying capacity.

[0059] S002: Conduct comparative analysis of complex well conditions based on the same gas well type.

[0060] In oil and gas exploration and development, there are many other types of wells besides the common horizontal and vertical wells. This application analyzes two common types of wells: horizontal and vertical. Common horizontal and vertical wells differ significantly in their structure and drilling direction. Horizontal wells are drilled vertically from the surface to a certain depth, after which the drill bit turns horizontally to continue drilling. Vertical wells, on the other hand, are drilled directly from the surface downward, with the borehole being drilled vertically along the bottom layer.

[0061] Horizontal gas wells consist of a vertical section, a build-up section (typically with an inclination of 30° to 90°), and a horizontal section, creating a multi-segment flow pattern. Compared to the single vertical flow path of a vertical well, the build-up and horizontal sections of a horizontal gas well can limit foam generation and lead to differences in foam distribution.

[0062] Since the horizontal section of a horizontal gas well can extend hundreds to thousands of meters, the longer the extension distance, the larger the reservoir range that the horizontal gas well can cover and the more oil and gas reserves that can be exposed. Therefore, the longer the horizontal section extension distance, the stronger the dynamic stability of the foam required.

[0063] The inclination of the inclination section reflects the process of the wellbore gradually changing from vertical to horizontal. The larger the inclination, the greater the technical difficulty and drilling cycle of the drilling process. That is, when the foam drainage agent acts, the foam liquid needs to be able to flow smoothly on the inclined well wall. Therefore, the greater the inclination, the more challenging the foam flow path is, and the required foam fluidity and stability are required to be higher.

[0064] Therefore, we can first conduct a comparative analysis of complex well conditions based on current horizontal gas wells and historical gas wells of the same type (i.e., horizontal gas wells) to reflect the corresponding foam dewatering agent application requirements under similar well conditions, as follows:

[0065] Because for the inclination section of a horizontal gas well, the inclination gradually increases as drilling progresses, and each different depth position has corresponding inclination data.

[0066] Therefore, what is obtained here is the inclination of the build-up section of the current horizontal gas well and each historical horizontal gas well when treated with foam drainage agent. At the same time, the extension distance of the current horizontal gas well and each historical horizontal gas well is obtained.

[0067] Furthermore, the similarity of the extension distance and the similarity of the inclination of the build-up section between the current horizontal gas well and each historical horizontal gas well is calculated.

[0068] As a preferred embodiment for calculating the similarity of extension distance and the similarity of inclination of the inclination section, this embodiment takes the current horizontal gas well and the j-th horizontal gas well in history as an example, compares the extension distance of the current horizontal gas well with that of the j-th horizontal gas well in history, uses the larger data as the denominator and the smaller data as the numerator, to determine the similarity of the extension distance between the current horizontal gas well and the j-th horizontal gas well in history, that is, to perform analysis through horizontal comparison of horizontal gas wells.

[0069] Compare the inclination of the build-up section of the current horizontal gas well with that of the j-th horizontal gas well in history, use the larger data as the denominator and the smaller data as the numerator to determine the similarity of the inclination of the build-up section of the current horizontal gas well and the j-th horizontal gas well in history, that is, analyze through longitudinal comparison of horizontal gas wells.

[0070] Furthermore, the similarity of the extension distance and the similarity of the inclination of the build-up section between the current horizontal gas well and the j-th horizontal gas well in history are forward fused to determine the basic scale similarity between the current horizontal gas well and the j-th horizontal gas well in history.

[0071] It can be understood that forward fusion is a fusion method such as addition and multiplication between data. The specific forward fusion method is determined by the implementer according to the actual situation, and this application does not impose any special restrictions.

[0072] In this embodiment, the product of the extension distance similarity and the build-up section inclination similarity between the current horizontal gas well and the jth horizontal gas well in history is used as the basic scale similarity between the current horizontal gas well and the jth horizontal gas well in history. In other embodiments, linear or exponential transformations can be performed on the extension distance similarity and the build-up section inclination similarity to change the degree to which they affect the basic scale similarity calculation result.

[0073] S003: Conduct comparative analysis of complex well conditions based on different gas well types.

[0074] The above process is based on the comparison of gas wells of the same type. However, different gas well types may exhibit different structural manifestations in their internal structural distribution. Therefore, when performing a comparative analysis of the complex well conditions of different gas well types by comparing the current horizontal gas well with other types of historical gas wells (specifically vertical wells in this embodiment), other factors can be used for indirect analysis, as follows:

[0075] Since the flow patterns in horizontal gas wells (such as slug flow, annular film flow, and mist flow) present more complex flow structures than the flow patterns in vertical wells (mainly bubbly flow and slug flow), more stable foam drainage agents are required in horizontal gas wells.

[0076] Horizontal gas wells usually have higher critical flow velocities due to different flow paths, which indicates that their flow patterns are more complex than those of vertical wells and are affected by more factors (such as gravity and buoyancy). Therefore, the difference in flow patterns between horizontal and vertical wells can be reflected by the difference in critical flow velocities.

[0077] However, due to the coexistence of multiple flow patterns in horizontal gas wells, different sections of horizontal gas wells (vertical section, deflection section, and horizontal section) exhibit different flow patterns and present different critical flow velocities. In particular, the deflection section is prone to form slug flow or oscillating impact flow. The critical flow velocity increases nonlinearly with increasing inclination, and the critical velocity is the highest at 50°.

[0078] Therefore, when the inclination of the inclination section is closer to 50 degrees, the critical flow velocity of the inclination section of the horizontal gas well (compared with the vertical and horizontal sections) will be more significant. Therefore, the proximity of the current inclination of the inclination section of the horizontal gas well to 50 degrees can be analyzed here. The greater the proximity, the greater the weight given to the critical flow velocity of the inclination section.

[0079] As a preferred embodiment, this embodiment subtracts the inclination of the current horizontal gas well's inclination section from 50 degrees and performs inverse normalization to determine the proximity of the inclination of the current horizontal gas well's inclination section to 50 degrees, and records it as the attention level of the critical velocity of the current horizontal gas well's inclination section.

[0080] Optionally, the inverse proportional mapping may be implemented by negative linear mapping, negative exponential mapping, or by setting adjustment parameters.

[0081] Furthermore, the critical flow velocities of the current horizontal gas well in the deflection section, vertical section, and horizontal section are obtained respectively.

[0082] The comprehensive critical flow rate of the current horizontal gas well is determined by combining the proximity of the current horizontal gas well inclination section to 50 degrees.

[0083] As a preferred embodiment, this embodiment multiplies the result of the proximity of the inclination of the current horizontal gas well's inclination section to 50 degrees by the critical flow velocity of the inclination section in the current horizontal gas well as the first product, and multiplies the result of the absolute value of the difference between the proximity of the inclination of the current horizontal gas well's inclination section to 50 degrees and the value 1 by the average critical velocity of the vertical section and the horizontal section in the current horizontal gas well as the second product. The first product and the second product are added to determine the comprehensive critical flow velocity of the current horizontal gas well.

[0084] Furthermore, the difference between the comprehensive critical flow velocity of the current horizontal gas well and the critical flow velocity of the historical vertical well is used to determine the similarity of the flow patterns of the current horizontal gas well and the historical vertical well.

[0085] As a preferred embodiment, for the mth vertical well in history, this embodiment subtracts the comprehensive critical flow velocity of the current horizontal gas well from the critical flow velocity of the mth vertical well in history, and performs inverse proportional normalization to determine the similarity of the flow pattern of the current horizontal gas well with the mth vertical well in history.

[0086] S004: Calculate the downhole environment similarity between the current horizontal gas well and each historical gas well.

[0087] The above process analyzes the current horizontal gas well and historical gas wells of different types from the perspective of gas well characteristics. That is, for historical gas wells of the same type as the current horizontal gas well, the gas well scale performance is analyzed; and for historical gas wells of different types as the current horizontal gas well, the flow pattern similarity performance is analyzed.

[0088] In addition to the above, the underground environmental data will have an impact on the performance of the foam drainage agent, such as high temperature and high pressure will reduce the stability of the foam drainage agent performance, and the high concentration of the mineralization will cause the foam drainage agent to 、 The double electric layer of plasma compressed liquid film affects foam stability, etc.

[0089] Therefore, we can further analyze the compatibility of downhole environmental conditions and foam dewatering agent performance based on the differences in downhole environmental data, such as downhole pressure and temperature.

[0090] Based on this, this application obtains the downhole environmental data of the current horizontal gas well and each gas well in history, wherein the downhole environmental data includes: downhole pressure, temperature, salinity and condensate content. The number of types of downhole environmental data is G, and the gth type of environmental data is , the average value of the historical g-type environmental data in all gas wells is .

[0091] Furthermore, the downhole environmental similarity between the current horizontal gas well and each historical gas well is calculated. For each type of downhole environmental data, the present application calculates the ratio of the element values of the current horizontal gas well and each historical gas well under the environmental data; the ratios of all environmental data are comprehensively processed to obtain the downhole environmental similarity between the current horizontal gas well and each historical gas well.

[0092] As a preferred embodiment, the downhole environment similarity between the current horizontal gas well and the cth gas well in history is For example, the calculation expression is:

[0093]

[0094] in, represents the similarity between the downhole environment of the current horizontal gas well and the cth gas well in history; norm represents the normalization function; G represents the number of types of downhole environmental data; represents the difference between the current horizontal gas well and the cth gas well in history under the gth environmental data. In this embodiment, the difference is determined by calculating the absolute value of the difference between the element values of the current horizontal gas well and the cth gas well in history under the gth environmental data. It represents the average value of the historical g-th environmental data in all gas wells.

[0095] It should be understood that By comparing the two, we can measure the difference in the overall data size of the environmental data between the current horizontal gas well and the g-th environmental data of the c-th gas well in history.

[0096] At this point, the similarity between the downhole environment of the current horizontal gas well and each historical gas well can be obtained.

[0097] S005: Determine the comprehensive similarity of the environment and well conditions by combining the downhole environment similarity and the comparative analysis results of the complex well conditions.

[0098] Therefore, based on the similarity between the downhole environment of the current horizontal gas well and each historical gas well, we can combine the complex well conditions analyzed for different types of gas wells in the above process to jointly analyze the comprehensive similarity between the two.

[0099] Therefore, here, the downhole environment similarity between the current horizontal gas well and each historical gas well is forwardly integrated with the comparative analysis results of complex well conditions to determine the comprehensive similarity of the environment and well conditions between the current horizontal gas well and each historical gas well.

[0100] As a preferred embodiment, this embodiment multiplies the downhole environmental similarity between the current horizontal gas well and each historical gas well by the complex well condition comparison analysis results, and then performs Softmax normalization to determine the comprehensive similarity between the current horizontal gas well and each historical gas well in terms of environment and well condition. Softmax normalization is a well-known technique and will not be further described.

[0101] Among them, when the historical corresponding gas well is a horizontal gas well, that is, the gas well type is the same as the current horizontal gas well, the complex well condition comparison analysis result is the basic scale similarity between the current horizontal gas well and the historical horizontal gas well; when the historical corresponding gas well is a vertical well, that is, the gas well type is different from the current horizontal gas well, the complex well condition comparison analysis result is the flow pattern similarity between the current horizontal gas well and the historical vertical well.

[0102] S006: Determine the actual liquid carrying performance of the foam drainage agent in the current horizontal gas well based on the comprehensive similarity of the environment and well conditions between the current horizontal gas well and each historical gas well, as well as the difference in liquid carrying capacity of the gas wells.

[0103] Due to the influence of environmental factors such as high temperature and high pressure and the characteristics of different gas well types, the performance of foam drainage agents will vary. The quantification of foam drainage agent performance is based on the amount of liquid carried after the foam drainage agent acts.

[0104] Based on this, the present application obtains the gas well liquid carrying capacity of the foam dewatering agent for the current horizontal gas well and each gas well in history. The gas well liquid carrying capacity of the current horizontal gas well is compared with the gas well liquid carrying capacity of the cth gas well in history to determine the liquid carrying capacity performance ratio of the current horizontal gas well to the cth gas well in history. In this way, we can obtain the liquid carrying capacity performance ratio of the current horizontal gas well to the cth gas well in history.

[0105] However, due to the different well conditions of different types of gas wells or within the same type of gas wells, the true performance of the foam dewatering agent may be obscured by more complex special environmental interference or gas well characteristics, making the performance of the current foam dewatering agent in horizontal gas wells not its true performance.

[0106] At the same time, considering that the foam drainage agent used in historical gas wells was not always the same, we can use the comprehensive similarity of the environment and well conditions of the current horizontal gas well and each historical gas well to correct the liquid carrying capacity performance ratio of the current horizontal gas well and the cth gas well in history, and combine the correction results of all historical gas wells to determine the actual liquid carrying performance of the foam drainage agent in the current horizontal gas well.

[0107] As a preferred embodiment, the calculation formula for the actual liquid carrying performance Y of the foam drainage agent of the current horizontal gas well is as follows:

[0108]

[0109] Where Y represents the actual liquid carrying performance of the foam dewatering agent in the current horizontal gas well; norm represents the normalization function; C represents the number of historical gas wells; Indicates the comprehensive similarity of the environment and well conditions between the current horizontal gas well and the cth gas well in history; It represents the performance ratio of the liquid carrying capacity of the current horizontal gas well to that of the cth gas well in history.

[0110] In this way, we can determine the actual liquid-carrying performance of current horizontal gas well foam dewatering agents.

[0111] S007: Determine the foam drainage agent performance test results of the current horizontal gas well using the actual liquid carrying performance.

[0112] Through the above process, we can determine the actual liquid carrying performance of the foam dewatering agent in the current horizontal gas well.

[0113] In this embodiment, a true liquid carrying performance threshold is preset to 0.65. When the true liquid carrying performance of the foam drainage agent of the current horizontal gas well is greater than or equal to the true liquid carrying performance threshold, the performance of the foam drainage agent of the current horizontal gas well is qualified; otherwise, the performance of the foam drainage agent of the current horizontal gas well is unqualified.

[0114] Based on the same inventive concept as the above method, an embodiment of the present application also provides a system for detecting the performance of a horizontal gas well foam drainage agent, comprising a memory, a processor, and a computer program stored in the memory and running on the processor. When the processor executes the computer program, it implements any one of the above-mentioned methods for detecting the performance of a horizontal gas well foam drainage agent.

[0115] Those skilled in the art will readily appreciate other embodiments of the present application after considering the specification and practicing the invention herein. This application is intended to cover any variations, uses, or adaptations of the present application that follow the general principles of the present application and include common knowledge or customary techniques in the art not invented herein.

[0116] It will be understood that the present application is not limited to the exact construction that has been described above and shown in the drawings, and that various modifications and changes may be made without departing from the scope thereof.

Claims

1. A method for testing the performance of a horizontal gas well foam dewatering agent, characterized in that: The method comprises the following steps: Obtain historical foam drainage agent related test data and current horizontal gas well foam drainage agent test data; Comparative analysis of gas well data between the current horizontal gas well and all historical gas wells, including comparative analysis of gas well data based on the same gas well type and comparative analysis of gas well data based on different gas well types; The gas well data comparison and analysis results are forward-fused with the downhole environment similarity between the current horizontal gas well and each historical gas well to determine the comprehensive similarity between the environment and well conditions of the current horizontal gas well and each historical gas well. The difference in liquid carrying capacity between the current horizontal gas well and each historical gas well is corrected using the comprehensive similarity of the environment and well conditions. The correction results of all historical gas wells are combined to determine the actual liquid carrying performance of the foam drainage agent in the current horizontal gas well. The actual liquid carrying performance is used to determine the performance test results of the foam dewatering agent in the current horizontal gas well.

2. The method for detecting the performance of a horizontal gas well foam dewatering agent according to claim 1, wherein: The comparative analysis of gas well data based on the same gas well type includes: Obtain the extension distance and inclination of the build-up section of the current horizontal gas well and each historical horizontal gas well; Calculate the similarity of the extension distance and the inclination of the build-up section between the current horizontal gas well and each historical horizontal gas well; The similarity of extension distance and the similarity of build-up section inclination are forward fused to determine the basic scale similarity between the current horizontal gas well and each historical horizontal gas well.

3. The method for detecting the performance of a horizontal gas well foam drainage agent according to claim 1, wherein: The comparative analysis of gas well data based on different gas well types includes: Analyze the proximity of the current horizontal gas well build-up section inclination to 50 degrees; respectively obtaining the critical flow velocities of the current horizontal gas well in the build-up section, the vertical section, and the horizontal section, and combining the proximity to determine the comprehensive critical flow velocity of the current horizontal gas well; The difference between the comprehensive critical flow velocity of the current horizontal gas well and the critical flow velocity of each historical vertical well is used to determine the similarity of the flow pattern between the current horizontal gas well and each historical vertical well.

4. The method for testing the performance of a horizontal gas well foam drainage agent according to claim 1, wherein: The method of determining the foam drainage agent performance test results of the current horizontal gas well using the actual liquid carrying performance includes: When the actual liquid carrying performance of the foam drainage agent of the current horizontal gas well is greater than or equal to the preset actual liquid carrying performance threshold, the performance of the foam drainage agent of the current horizontal gas well is qualified; otherwise, the performance of the foam drainage agent of the current horizontal gas well is unqualified.

5. The method for testing the performance of a horizontal gas well foam drainage agent according to claim 2, wherein: The calculation of the similarity of the extension distance and the similarity of the inclination of the build-up section between the current horizontal gas well and each of the historical horizontal gas wells includes: Compare the minimum and maximum extension distances of the current horizontal gas well with those of each historical horizontal gas well to determine the similarity of the extension distances; The minimum and maximum values of the build-up section inclinations of the current horizontal gas well and each historical horizontal gas well are compared to determine the similarity of the build-up section inclinations.

6. The method for testing the performance of a horizontal gas well foam drainage agent according to claim 3, wherein: The method for determining the comprehensive critical flow rate of the current horizontal gas well includes: The result of multiplying the proximity of the current horizontal gas well by the critical flow velocity of the deflection section in the current horizontal gas well is recorded as a first product; and multiplying the absolute value of the difference between the proximity of the current horizontal gas well and the value 1 by the average critical velocity of the vertical section and the horizontal section of the current horizontal gas well, recording the result as the second product; The first product and the second product are added together to determine the comprehensive critical flow rate of the current horizontal gas well.

7. The method for testing the performance of a horizontal gas well foam drainage agent according to claim 1, wherein: The method for obtaining the downhole environment similarity between the current horizontal gas well and each historical gas well includes: For each downhole environmental data, calculate the ratio of the element value of the current horizontal gas well to that of each historical gas well under each environmental data; The ratios of all environmental data are comprehensively processed to obtain the downhole environmental similarity between the current horizontal gas well and each historical gas well.

8. The method for testing the performance of a horizontal gas well foam drainage agent according to claim 3, wherein: The method for determining the similarity between the flow patterns of the current horizontal gas well and each of the historical vertical wells includes: For the mth vertical well in history, the comprehensive critical flow velocity of the current horizontal gas well is subtracted from the critical flow velocity of the mth vertical well in history, and inverse normalization is performed to determine the similarity of the flow pattern between the current horizontal gas well and the mth vertical well in history.

9. A method for testing the performance of a horizontal gas well foam dewatering agent according to any one of claims 1 to 8, characterized in that: The acquisition of historical foam drainage agent related test data and current horizontal gas well foam drainage agent test data includes: The historical foam drainage agent related detection data includes related detection data of multiple horizontal gas wells and multiple vertical wells; The relevant detection data and test data include: gas well data, gas well production data, downhole environment data, and application effect of foam drainage agent; Among them, gas well data includes: extension distance, inclination of the inclination section and critical flow rate; downhole environmental data includes: downhole pressure, temperature, salinity and condensate oil content; the application effect of foam drainage agent includes: liquid carrying capacity.

10. A system for detecting the performance of a horizontal gas well foam dewatering agent, comprising a memory, a processor, and a computer program stored in the memory and running on the processor, characterized in that: When the processor executes the computer program, the method for detecting the performance of a horizontal gas well foam drainage agent according to any one of claims 1 to 9 is implemented.

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