Method and system for detecting performance of foam drainage agent of horizontal gas well

Abstract

The invention relates to the technical field of horizontal gas well foam drainage agent performance detection, in particular to a horizontal gas well foam drainage agent performance detection method and system, and the method comprises the steps: obtaining historical foam drainage agent related detection data and current horizontal gas well foam drainage agent test data; performing complex well condition comparative analysis on the current horizontal gas well and all historical gas wells; the analysis result and the underground environment similarity of the current horizontal gas well and each historical gas well are subjected to forward fusion, and the gas well liquid carrying quantity difference of the current horizontal gas well and each historical gas well is corrected, so that the real liquid carrying performance of the foam drainage agent of the current horizontal gas well is determined; and determining the performance detection result of the foam drainage agent of the current horizontal gas well. The invention aims to avoid the excessive interference on the performance detection of the foam drainage agent of the horizontal gas well caused by the excessive complex well condition performance of the horizontal gas well and the extreme underground environment influence.

Description

Technical Field

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

[0002] Foam drainage agent for horizontal gas wells is a chemical agent with surfactant as the core. It is mainly used to solve the problem of production capacity decline caused by bottom-well liquid accumulation in the middle and late stages of gas well development. Its core function is to reduce the gas-liquid interfacial tension, form stable low-density foam, and use the airflow to carry the bottom-well liquid to the ground, thereby restoring or increasing the gas well production. However, horizontal gas wells are long and have large well inclinations, so liquids are more likely to be retained. Traditional drainage methods such as pumping and gas lift are inefficient and costly in horizontal gas wells. Foam drainage agent becomes an economical and efficient solution through physical-chemical synergy.

[0003] The performance evaluation of current foam drainage agents shows the following defects: (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 detection 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.

[0004] Although the performance testing system of foam drainage agents has been gradually improved, the current horizontal gas wells are facing more extreme environmental complexity, such as high temperature, high mineralization, high condensate content, ultra-deep well pressure, etc. The abstract of the paper "Development of Foam Drainage Agents and Research on Drainage Technology under Extreme Environments" explains that the actual foam drainage effect is affected by many factors, such as high temperature, mineralization, condensate content, methanol content, etc.

[0005] (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 the 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. This may cause significant interference to the performance test results of the foam drainage agents. Summary of the invention

[0006] In order to solve the above technical problems, the present application provides a method and system for detecting the performance of a horizontal gas well foam drainage agent. The technical solutions adopted are as follows: 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: Obtain historical foam drainage agent related test data and current horizontal gas well foam drainage agent test data; Conducting a comparative analysis of the complex well conditions of the current horizontal gas wells and all the historical gas wells, including a comparative analysis of the complex well conditions based on the same gas well type and a comparative analysis of the complex well conditions based on different gas well types; The results of the complex well condition comparison analysis and the downhole environment similarity between the current horizontal gas well and each historical gas well are forwardly integrated 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 gas well liquid carrying capacity between the current horizontal gas well and each gas well in history is corrected using the comprehensive similarity of the environment and well conditions, and 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 foam dewatering agent performance test results for the current horizontal gas well.

[0007] Preferably, the comparative analysis of complex well conditions based on the same gas well type includes: Obtain the extension distance and inclination of the inclination 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 the extension distance and the similarity of the inclination of the build-up section are forwardly fused to determine the basic scale similarity between the current horizontal gas well and each historical horizontal gas well.

[0008] Preferably, the comparative analysis of complex well conditions 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 rates of the current horizontal gas well in the deflection section, the vertical section and the horizontal section, and combining the proximity to determine the comprehensive critical flow rate 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.

[0009] 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: 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.

[0010] Preferably, the calculation of the similarity of the extension distance and the similarity of the inclination of the deflection section between the current horizontal gas well and each historical horizontal gas well 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 inclinations of the build-up sections of the current horizontal gas well and each historical horizontal gas well are compared to determine the similarity of the inclinations of the build-up sections.

[0011] Preferably, 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 the 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 in the current horizontal gas well, and 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.

[0012] Preferably, 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 the environmental data; The ratios of all environmental data are processed comprehensively to obtain the downhole environmental similarity between the current horizontal gas well and each historical gas well.

[0013] Preferably, the method for determining the similarity of the flow pattern between the current horizontal gas well and each historical vertical well comprises: For the mth vertical well in history, the comprehensive critical flow rate of the current horizontal gas well is subtracted from the critical flow rate 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.

[0014] Preferably, the acquisition of historical foam drainage agent related detection 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, underground environment data, and application effect of foam drainage agent; Among them, gas well data include: extension distance, inclination of the inclination section and critical flow rate; downhole environmental data include: downhole pressure, temperature, mineralization and condensate content; the application effect of foam drainage agent includes: liquid carrying capacity.

[0015] 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.

[0016] This application has at least the following beneficial effects: 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, and based on the liquid carrying performance of the foam drainage agent, determine the actual liquid carrying performance of the current horizontal gas well 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

[0017] In order to more clearly illustrate the technical solutions and advantages in the embodiments of the present application or the prior art, the drawings required for use in the embodiments or the prior art descriptions are briefly introduced below. 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 creative work.

[0018] Figure 1 A flow chart of a method for detecting the performance of a foam drainage agent for a horizontal gas well provided in one embodiment of the present application; Figure 2 A flowchart of the analysis process for detecting the performance of foam drainage agents in current horizontal gas wells provided in one embodiment of the present application. DETAILED DESCRIPTION

[0019] An 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: Obtain historical foam drainage agent related test data and current horizontal gas well foam drainage agent test data; Conducting a comparative analysis of the complex well conditions of the current horizontal gas wells and all the historical gas wells, including a comparative analysis of the complex well conditions based on the same gas well type and a comparative analysis of the complex well conditions based on different gas well types; The results of the complex well condition comparison analysis and the downhole environment similarity between the current horizontal gas well and each historical gas well are forwardly integrated 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 gas well liquid carrying capacity between the current horizontal gas well and each gas well in history is corrected using the comprehensive similarity of the environment and well conditions, and 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 foam dewatering agent performance test results for the current horizontal gas well.

[0020] Among them, this application specifically analyzes the process of the above steps. The analysis process flow chart of the foam drainage agent performance detection of the current horizontal gas well is as shown in the attached Figure 2 As shown, specifically: S001: Obtain historical foam drainage agent related test data and current horizontal gas well foam drainage agent test data.

[0021] When a gas well enters the middle and late stages of production, the formation pressure decreases, and the gas flow rate is insufficient to carry the bottom hole liquid (such as formation water and condensate oil), resulting in liquid accumulation, which leads to increased back pressure and a sharp drop in production. In this way, the use of foam drainage agents to form low-density foam, and the bottom hole liquid is carried to the surface with the help of airflow, thereby restoring or increasing the gas well production.

[0022] 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 the characteristics of different types of gas wells.

[0023] Therefore, the relevant detection 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.

[0024] Among them, the historical foam drainage agent related detection data includes relevant detection data of multiple horizontal gas wells and multiple vertical wells; the relevant detection data and test data both include: gas well data, gas well production data, downhole environment data, and application effect of foam drainage agent.

[0025] Among them, gas well data include: extension distance, inclination of the inclination section and critical flow rate; downhole environmental data include: downhole pressure, temperature, mineralization and condensate content; the application effect of foam drainage agent includes: liquid carrying capacity.

[0026] S002: Comparative analysis of complex well conditions based on the same gas well type.

[0027] In the exploration and development of oil and gas, in addition to the common horizontal gas wells and vertical wells, there are many other types of wells. This application analyzes two common gas wells, horizontal gas wells and vertical wells. There are obvious differences between the common horizontal gas wells and vertical wells in the well structure and drilling direction. The horizontal gas well is a wellbore that is drilled vertically from the surface to a certain depth, and the drill bit will turn to the horizontal direction to continue drilling; while the vertical well is drilled directly from the surface vertically downward, and the drilling is carried out along the vertical direction of the bottom layer.

[0028] Horizontal gas wells contain vertical sections, deflection sections (usually with an inclination of 30°~90°) and horizontal sections, forming a multi-section flow pattern. Compared with the single vertical flow path of vertical wells, the deflection section and horizontal section of horizontal gas wells will lead to limited foam generation and different foam distribution.

[0029] 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.

[0030] The inclination of the inclination section reflects the process of the wellbore gradually changing from a vertical direction to a horizontal direction. 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 higher the fluidity and stability requirements of the foam are.

[0031] Therefore, we can first conduct a comparative analysis of the complex well conditions based on the current horizontal gas wells and the historical gas wells of the same type (i.e. horizontal gas wells), so as to reflect the corresponding foam drainage agent application requirements under similar well conditions, as follows: 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.

[0032] Therefore, what is obtained here is the inclination of the inclination section of the current horizontal gas well and each historical horizontal gas well when treated with a foam drainage agent. At the same time, the extension distance of the current horizontal gas well and each historical horizontal gas well is obtained.

[0033] 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.

[0034] As a preferred embodiment for calculating the similarity of extension distance and the similarity of inclination of the inclined section, this embodiment takes the current horizontal gas well and the j-th horizontal gas well in history as examples, compares the extension distance of the current horizontal gas well with that of the j-th horizontal gas well in history, and 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 analyze through lateral comparison of horizontal gas wells.

[0035] Compare the inclination of the current horizontal gas well with that of the jth 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 current horizontal gas well with that of the jth horizontal gas well in history, that is, analyze through longitudinal comparison of horizontal gas wells.

[0036] Furthermore, the similarity of the extension distance and the similarity of the inclination of the deflection section between the current horizontal gas well and the jth horizontal gas well in history are forwardly fused to determine the basic scale similarity between the current horizontal gas well and the jth horizontal gas well in history.

[0037] 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.

[0038] In this embodiment, the product of the similarity of the extension distance between the current horizontal gas well and the jth horizontal gas well in history and the similarity of the inclination of the deflection section is used as the basic scale similarity between the current horizontal gas well and the jth horizontal gas well in history. In other embodiments, the similarity of the extension distance and the similarity of the inclination of the deflection section can be transformed linearly or exponentially respectively to change the influence of the two on the calculation result of the basic scale similarity.

[0039] S003: Comparative analysis of complex well conditions based on different gas well types.

[0040] The above process is based on the comparison of gas wells of the same type. Different gas well types have different structural performances in the internal structure distribution of the gas wells. Therefore, when comparing and analyzing the complex well conditions of different gas well types through the current horizontal gas well and other types of historical gas wells (specifically vertical wells in this embodiment), other factors can be used for indirect analysis, as follows: Since the flow patterns in horizontal gas wells (such as slug flow, annular film flow, and mist flow) present a more complex flow structure than the flow patterns in vertical wells (mainly bubbly flow and slug flow), a more stable foam drainage agent is required in horizontal gas wells.

[0041] 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, buoyancy, etc.). Therefore, the difference in flow patterns between horizontal gas wells and vertical wells can be reflected by the difference in critical flow velocities.

[0042] However, due to the coexistence of multiple flow patterns in horizontal gas wells, different sections of horizontal gas wells (vertical section, deflection section, horizontal section) exhibit different flow patterns and different critical flow velocity performances, especially the deflection section, which is prone to form slug flow or oscillating impact flow. The critical flow velocity increases nonlinearly with the increase of the inclination, among which the critical velocity is the largest at 50°.

[0043] Therefore, when the inclination of the inclination section is closer to 50 degrees, the inclination section in the horizontal gas well (compared with the vertical section and the horizontal section) will show a more significant critical flow velocity. 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.

[0044] As a preferred embodiment, this embodiment subtracts the inclination of the current horizontal gas well's build section from 50 degrees and performs inverse normalization to determine the proximity of the current horizontal gas well's build section inclination to 50 degrees, and records it as the attention level of the critical velocity of the current horizontal gas well's build section.

[0045] Optionally, the inverse proportional mapping may be implemented by negative linear mapping, negative exponential mapping, or by setting adjustment parameters.

[0046] Furthermore, the critical flow velocities of the current horizontal gas well in the deflection section, the vertical section and the horizontal section are obtained respectively.

[0047] 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.

[0048] As a preferred embodiment, this embodiment multiplies the result of the proximity of the inclination of the current horizontal gas well building section to 50 degrees by the critical flow velocity of the building 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 building 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, and adds the first product to the second product to determine the comprehensive critical flow velocity of the current horizontal gas well.

[0049] 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 pattern between the current horizontal gas well and the historical vertical well.

[0050] 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 between the current horizontal gas well and the mth vertical well in history.

[0051] S004: Calculate the similarity of the downhole environment between the current horizontal gas well and each historical gas well.

[0052] The above process is an analysis of the current horizontal gas wells 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 similarity of flow pattern performance is analyzed.

[0053] In addition to the above, the underground environmental data will have an impact on the performance of the foam drainage agent. For example, high temperature and high pressure will reduce the stability of the foam drainage agent, and high concentration will appear under the effect of mineralization. , The double electrical layer of plasma compressed liquid film affects foam stability, etc.

[0054] Therefore, we can further analyze the compatibility of downhole environmental conditions and foam dewatering agent performance based on the downhole environmental data, namely the differences in downhole pressure, temperature, etc.

[0055] 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-th environmental data in all gas wells is .

[0056] 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.

[0057] 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: in, represents the similarity of the downhole environment between 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, which 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 in this embodiment; It represents the average value of the historical g-th environmental data in all gas wells.

[0058] It should be understood that By comparing the two, we can measure the data difference between the g-th environmental data of the current horizontal gas well and the g-th environmental data of the historical c-th gas well in the overall data size of the environmental data. At this point, the similarity of the downhole environment between the current horizontal gas well and each historical gas well can be obtained.

[0059] 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.

[0060] 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 by the above process for different types of gas wells in history to jointly analyze the comprehensive similarity between the two.

[0061] Therefore, here, the downhole environment similarity and complex well condition comparison analysis results between the current horizontal gas well and each historical gas well are forwardly integrated to determine the comprehensive similarity of the environment and well condition between the current horizontal gas well and each historical gas well.

[0062] As a preferred embodiment, this embodiment multiplies the downhole environment similarity and complex well condition comparison analysis results between the current horizontal gas well and each historical gas well, and performs Softmax normalization to determine the comprehensive similarity of the environment and well condition between the current horizontal gas well and each historical gas well. Softmax normalization is a well-known technology and will not be described in detail.

[0063] 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 comparative analysis result of its complex well conditions 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 comparative analysis result of its complex well conditions is the flow pattern similarity between the current horizontal gas well and the historical vertical well.

[0064] S006: Determine the actual liquid carrying performance of the foam drainage agent of the current horizontal gas well by combining the comprehensive similarity of the environment and well conditions of the current horizontal gas well with those of each historical gas well and the difference in liquid carrying capacity of the gas wells.

[0065] Due to 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 by the foam drainage agent after action.

[0066] Based on this, the present application obtains the gas well liquid carrying capacity of the foam drainage agent of 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 and the cth gas well in history. In this way, we can obtain the liquid carrying capacity performance ratio of the current horizontal gas well and the cth gas well in history.

[0067] However, due to the different well conditions in different types of gas wells or in the same type of gas wells, the true performance of the foam drainage agent may be obscured by more complex special environmental interference or gas well characteristics, making the performance of the foam drainage agent in the current horizontal gas well not its true performance.

[0068] At the same time, considering that the historical foam drainage agent was not always the same when it was applied to the historical gas wells, we can use the comprehensive similarity of the environment and well conditions between the current horizontal gas well and each historical gas well to correct the liquid carrying capacity performance ratio between 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.

[0069] As a preferred embodiment, the calculation formula of the actual liquid carrying performance Y of the foam drainage agent of the current horizontal gas well is as follows: Among them, Y represents the actual liquid carrying performance of the foam drainage agent of 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 the cth gas well in history.

[0070] In this way, we can determine the actual liquid-carrying performance of current foam dewatering agents in horizontal gas wells.

[0071] S007: Determine the foam drainage agent performance test results of the current horizontal gas well using the actual liquid carrying performance.

[0072] Through the above process, we can determine the actual liquid carrying performance of the foam drainage agent in the current horizontal gas well.

[0073] In this embodiment, the real liquid carrying performance threshold is preset to 0.65. When the real liquid carrying performance of the foam drainage agent of the current horizontal gas well is greater than or equal to the real 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.

[0074] 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, 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.

[0075] Those skilled in the art will readily appreciate other embodiments of the present application after considering the specification and practicing the invention herein. The present application is intended to cover any variations, uses or adaptations of the present application, which follow the general principles of the present application and include common knowledge or customary technical means in the art that are not invented by the present application.

[0076] It should 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 detecting the performance of a horizontal gas well foam drainage 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; Conducting a comparative analysis of the complex well conditions of the current horizontal gas wells and all the historical gas wells, including a comparative analysis of the complex well conditions based on the same gas well type and a comparative analysis of the complex well conditions based on different gas well types; The results of the complex well condition comparison analysis and the downhole environment similarity between the current horizontal gas well and each historical gas well are forwardly integrated 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 gas well liquid carrying capacity between the current horizontal gas well and each gas well in history is corrected using the comprehensive similarity of the environment and well conditions, and 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 foam dewatering agent performance test results for the current horizontal gas well.

2. A method for detecting the performance of a horizontal gas well foam drainage agent as claimed in claim 1, characterized in that: The comparative analysis of complex well conditions based on the same gas well type includes: Obtain the extension distance and inclination of the inclination 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 the extension distance and the similarity of the inclination of the build-up section are forwardly fused to determine the basic scale similarity between the current horizontal gas well and each historical horizontal gas well.

3. A method for detecting the performance of a horizontal gas well foam drainage agent as claimed in claim 1, characterized in that: The comparative analysis of complex well conditions 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 rates of the current horizontal gas well in the deflection section, the vertical section and the horizontal section, and combining the proximity to determine the comprehensive critical flow rate 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. A method for detecting the performance of a horizontal gas well foam drainage agent as claimed in claim 1, characterized in that: 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: 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. A method for detecting the performance of a horizontal gas well foam drainage agent as claimed in claim 2, characterized in that: The calculation of the similarity of the extension distance and 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 inclinations of the build-up sections of the current horizontal gas well and each historical horizontal gas well are compared to determine the similarity of the inclinations of the build-up sections.

6. A method for testing the performance of a horizontal gas well foam drainage agent as claimed in claim 3, characterized in that: 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 the 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 in the current horizontal gas well, and 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. A method for testing the performance of a horizontal gas well foam drainage agent as claimed in claim 1, characterized in that: 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 the environmental data; The ratios of all environmental data are processed comprehensively to obtain the downhole environmental similarity between the current horizontal gas well and each historical gas well.

8. A method for testing the performance of a horizontal gas well foam drainage agent as claimed in claim 3, characterized in that: The method for determining the similarity of 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 rate of the current horizontal gas well is subtracted from the critical flow rate 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 detecting the performance of a horizontal gas well foam drainage 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, underground environment data, and application effect of foam drainage agent; Among them, gas well data include: extension distance, inclination of the inclination section and critical flow rate; downhole environmental data include: downhole pressure, temperature, mineralization and condensate content; the application effect of foam drainage agent includes: liquid carrying capacity.

10. A system for detecting the performance of a foam drainage agent for a horizontal gas well, 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 as described in any one of claims 1 to 9 is implemented.

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