Gas-liquid two-phase flow reverse iteration production profile interpretation method, system, device and medium

Abstract

The present application belongs to the technical field of oil and gas exploitation, and relates to a gas-liquid two-phase flow reverse iteration production profile interpretation method, system, device and medium. According to the wellbore inner diameter PC value, fluid velocity profile correction coefficient and production value of the production layer, the wellbore fluid apparent velocity calculation value is obtained, and the wellbore fluid average velocity value is obtained according to the wellbore fluid apparent velocity calculation value. The wellbore fluid holdup calculation value is obtained according to the difference between the gas velocity and the liquid velocity. The gas production value of the current layer of the production layer is obtained according to the difference between the gas velocity and the liquid velocity, the wellbore fluid average velocity value and the wellbore fluid holdup calculation value. By judging whether the difference between the gas production value of the current layer of the production layer and the production value of the production layer is within the threshold range, the iteration of the gas production value of the current layer of the production layer and the acquisition of the gas production value of the next layer of the production layer are carried out, and the present application is beneficial to the accurate interpretation of the gas-liquid two-phase flow production logging of the ultra-deep well.

Description

Technical Field

[0001] This invention belongs to the field of oil and gas extraction technology, and relates to a method, system, equipment and medium for interpreting the reverse iterative production profile of gas-liquid two-phase flow. Background Technology

[0002] Traditional methods for interpreting gas-liquid two-phase flow production profiles rely on drift models. Drift models are sophisticated physical models that deeply consider the crucial factor of the relative velocity between the gas and liquid phases, while also taking into account the distribution of porosity and velocity across the flow cross-section—all important factors influencing the flow characteristics of gas-liquid two-phase flows. By introducing turbulent flow relationships, this model can accurately calculate the liquid holdup, i.e., the proportion of liquid in the gas-liquid mixture under specific conditions.

[0003] In typical vertical well environments, due to relatively stable temperature and pressure conditions, the flow characteristics of the gas-liquid two-phase system are relatively regular. Therefore, drift models can provide high interpretation accuracy and meet the needs of production practice. However, in the special environment of ultra-deep wells, which refer to oil wells with a surface depth exceeding 6000 meters, the situation is quite different. Due to the high temperature and pressure conditions brought about by the well depth, the flow patterns of the gas-liquid two-phase system become extremely complex. Specifically, high temperature and pressure cause changes in the physical properties of the gas-liquid two-phase system, such as density and viscosity, which in turn affect their flow characteristics, making it difficult for traditional drift models to accurately describe and predict the flow behavior of the gas-liquid two-phase system.

[0004] In summary, traditional methods for interpreting gas-liquid two-phase flow production profiles suffer from insufficient accuracy in description. Summary of the Invention

[0005] The purpose of this invention is to provide a method, system, equipment, and medium for interpreting gas-liquid two-phase flow reverse iterative production profiles, in order to solve the technical problem that traditional gas-liquid two-phase flow production profile interpretation methods are not accurate enough. This invention can accurately obtain the gas production value of each production layer, which is beneficial to the accurate interpretation of gas-liquid two-phase flow production logging in ultra-deep wells.

[0006] To achieve the above objectives, the present invention employs the following technical solution: In a first aspect, the present invention provides a method for interpreting the reverse iterative production profile of a gas-liquid two-phase flow, comprising the following steps: The apparent velocity of the fluid in the wellbore is calculated based on the wellbore inner diameter PC value, the fluid velocity profile correction coefficient, and the production value of the producing layer. The average velocity of the fluid inside the wellbore is then calculated based on the apparent velocity of the fluid in the wellbore. The wellbore fluid holdup is calculated based on the difference between gas velocity and liquid velocity. The gas production value of the current production layer is obtained based on the difference between gas velocity and liquid velocity, the average fluid velocity in the wellbore, and the calculated fluid holdup in the wellbore. If the difference between the gas production value of the current producing layer and the production value of the producing layer is within the threshold range, then the gas production value of the current producing layer is used as the production value of the producing layer, and the gas production value of the next producing layer is obtained. Otherwise, the gas production value of the current producing layer replaces the production value of the producing layer, and the apparent velocity of the wellbore fluid in the current layer is recalculated until the difference between the gas production value of the current producing layer and the production value of the producing layer is within the threshold range.

[0007] Secondly, the present invention provides a system for interpreting reverse iterative production profiles of gas-liquid two-phase flow, comprising: Wellbore fluid apparent velocity acquisition module: used to obtain the calculated value of the wellbore fluid apparent velocity based on the wellbore inner diameter PC value, fluid velocity profile correction coefficient and production value of the producing layer, and to obtain the average velocity value of the fluid inside the wellbore based on the calculated value of the wellbore fluid apparent velocity. Fluid holdup acquisition module: used to obtain the calculated value of wellbore fluid holdup based on the difference between gas velocity and liquid velocity; Gas production value acquisition module: used to obtain the gas production value of the current production layer based on the difference between gas velocity and liquid velocity, the average fluid velocity in the wellbore, and the calculated fluid holdup in the wellbore. Judgment Loop Module: Used to determine the gas production value and production value of the current producing layer. If the difference between the gas production value and the production value of the current producing layer is within the threshold range, the gas production value of the current producing layer is used as the production value of the producing layer, and the gas production value of the next producing layer is obtained. Otherwise, the gas production value of the current producing layer replaces the production value of the producing layer, and the apparent velocity calculation value of the wellbore fluid for the current producing layer is obtained again, until the difference between the gas production value and the production value of the current producing layer is within the threshold range.

[0008] Thirdly, the present invention provides an electronic device, comprising: a processor; a memory for storing computer program instructions; and steps for implementing a method for reverse iterative production profile interpretation of gas-liquid two-phase flow when executing the computer program.

[0009] Fourthly, the present invention provides a storage medium storing computer program instructions, which are loaded and executed by a processor, wherein the processor executes a method for interpreting gas-liquid two-phase flow reverse iterative generation profiles.

[0010] Fifthly, the present invention provides a computer program product, the computer program product including computer instructions, the computer instructions instructing a computer to execute a method for reverse iterative generation of gas-liquid two-phase flow profile interpretation.

[0011] Compared with the prior art, the present invention has the following beneficial effects: 1. The method of this invention obtains the apparent velocity value of the wellbore fluid based on the wellbore inner diameter (PC) value, the fluid velocity profile correction coefficient, and the production rate of the producing layer; obtains the average velocity value of the fluid within the wellbore based on the apparent velocity value; obtains the liquid holdup value of the wellbore fluid based on the difference between the gas velocity and the liquid velocity; and obtains the gas production rate of the producing layer in the current section based on the difference between the gas velocity and the liquid velocity, the average velocity value of the fluid within the wellbore, and the liquid holdup value of the wellbore fluid. By comprehensively considering multiple key parameters of the gas-liquid two-phase flow, the accuracy and reliability of the gas production calculation are ensured. If the difference between the gas production value and the production value of the current producing layer is within a threshold range, then the gas production value of the current producing layer is used as the production value of the producing layer to obtain the gas production value of the next producing layer. Otherwise, the gas production value of the current producing layer replaces the production value of the producing layer, and the calculated apparent velocity value of the wellbore fluid for the current producing layer is obtained again, until the difference between the gas production value and the production value of the current producing layer is within the threshold range. That is, if the difference exceeds the threshold, iterative correction is performed until the requirements are met, ensuring the accuracy of gas production calculation and improving the reliability of production profile interpretation. This invention addresses the current state of production logging interpretation in ultra-deep wells by using an iteratively optimized calculation method to obtain the gas production value of the producing layer, which can improve the accuracy of production logging interpretation and provide a scientific basis for dynamic monitoring of production logging.

[0012] 2. The system of the present invention includes: a wellbore fluid apparent velocity acquisition module, a fluid holdup acquisition module, a gas production value acquisition module, and a circulation judgment module; the wellbore fluid apparent velocity acquisition module is used to acquire a calculated value of the wellbore fluid apparent velocity based on the wellbore inner diameter PC value, the fluid velocity profile correction coefficient, and the production value of the producing layer, and to acquire the average velocity value of the fluid in the wellbore based on the calculated value of the wellbore fluid apparent velocity; the fluid holdup acquisition module is used to acquire a calculated value of the wellbore fluid holdup based on the difference between the gas velocity and the liquid velocity; the gas production value acquisition module is used to acquire a calculated value of the wellbore fluid holdup based on the difference between the gas velocity and the liquid velocity, the average velocity value of the fluid in the wellbore, and the wellbore fluid holdup value. The liquid rate calculation value obtains the gas production value of the current producing layer. The judgment and circulation module is used to judge the gas production value of the current producing layer and the production value of the producing layer. If the difference between the gas production value of the current producing layer and the production value of the producing layer is within a threshold range, the gas production value of the current producing layer is used as the production value of the producing layer to obtain the gas production value of the next producing layer. Otherwise, the gas production value of the current producing layer replaces the production value of the producing layer, and the apparent velocity calculation value of the wellbore fluid for the current layer is re-obtained until the difference between the gas production value of the current producing layer and the production value of the producing layer is within the threshold range. The various modules work together to accurately obtain the gas production value of the producing layer in each layer, which is beneficial to the accurate interpretation of gas-liquid two-phase flow production logging in ultra-deep wells.

[0013] 3. The electronic equipment, storage medium and computer program products of this invention can also accurately obtain the gas production value of each layer of the producing layer, which is beneficial to the accurate interpretation of gas-liquid two-phase flow production logging in ultra-deep wells. Attached Figure Description

[0014] Figure 1 This is a flowchart of a method according to an embodiment of the present invention; Figure 2 This is a flowchart of the method of the present invention; Figure 3 This is a system module connection diagram of the present invention. Detailed Implementation

[0015] To enable those skilled in the art to better understand the present invention, the technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort should fall within the scope of protection of the present invention.

[0016] It should be noted that the terms "first," "second," etc., in the specification and accompanying drawings of this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of the invention described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0017] The present invention will now be described in further detail with reference to the accompanying drawings: See Figure 1 and Figure 2 This invention discloses a method for interpreting the reverse iterative production profile of gas-liquid two-phase flow, comprising the following steps: The apparent velocity of the fluid in the wellbore is calculated based on the wellbore inner diameter PC value, the fluid velocity profile correction coefficient, and the production value of the producing layer. The average velocity of the fluid inside the wellbore is then calculated based on the apparent velocity of the fluid in the wellbore. The wellbore fluid holdup is calculated based on the difference between gas velocity and liquid velocity. The gas production rate of the current producing zone is obtained by calculating the difference between gas and liquid velocities, the average fluid velocity within the wellbore, and the fluid holdup in the wellbore. By comprehensively considering multiple key parameters of the gas-liquid two-phase flow, the accuracy and reliability of the gas production calculation are ensured.

[0018] If the difference between the gas production value and the production value of the current producing layer is within a threshold range, then the gas production value of the current producing layer is used as the production value of the producing layer to obtain the gas production value of the next producing layer. Otherwise, the gas production value of the current producing layer replaces the production value of the producing layer, and the calculated apparent velocity value of the wellbore fluid for the current producing layer is obtained again, until the difference between the gas production value and the production value of the current producing layer is within the threshold range. In other words, if the difference exceeds the threshold, iterative correction is performed until the requirement is met, ensuring the accuracy of gas production calculation and improving the reliability of production profile interpretation. This provides more accurate and reliable gas production data for oil and gas field development and management, helping to optimize production strategies, improve recovery rates, and enhance economic benefits.

[0019] Example 1: See Figure 1 and Figure 2 This embodiment discloses a method for interpreting the reverse iterative generation profile of gas-liquid two-phase flow, including the following steps: S1. The apparent velocity of the fluid in the wellbore is calculated based on the inner diameter PC value, the fluid velocity profile correction coefficient, and the production value of the producing layer. The average velocity of the fluid in the wellbore is then calculated based on the apparent velocity of the fluid in the wellbore. Preferably, the process of obtaining the wellbore inner diameter PC value is as follows: The wellbore inner diameter PC value is obtained based on the wellbore inner diameter using the following formula:

[0020] in, PC value represents the inner diameter of the wellbore, in units of ; This is the inner diameter of the well shaft, in mm.

[0021] Preferably, the formula for obtaining the apparent velocity value of the wellbore fluid is as follows:

[0022] in, Q is the calculated apparent velocity of the fluid in the wellbore, in m / min; Q is the production rate of the producing layer, in m³ / min. 3 / d; PC value represents the inner diameter of the wellbore. It is the fluid velocity profile correction coefficient, which is dimensionless and a known parameter; Preferably, the formula for obtaining the average velocity value of the fluid inside the wellbore is as follows:

[0023] in, It is the average velocity of the fluid inside the wellbore, in m / min. This is the calculated value of the apparent velocity of the fluid in the wellbore. It is the fluid velocity profile correction coefficient, which is dimensionless and a known parameter.

[0024] S2, the wellbore fluid holdup is calculated based on the difference between gas velocity and liquid velocity, as follows:

[0025] in, This is a dimensionless calculated value of the fluid holdup in the wellbore. It is the difference between the gas velocity and the liquid velocity in a gas-liquid two-phase flow, and the unit is m / min.

[0026] S3, based on the difference between gas velocity and liquid velocity, the average fluid velocity in the wellbore, and the calculated fluid holdup in the wellbore, obtain the gas production value of the current producing layer, as follows: The cross-sectional area of ​​the wellbore is obtained based on the inner diameter of the wellbore. The gas production rate of the producing layer is obtained based on the difference between gas velocity and liquid velocity, the cross-sectional area of ​​the wellbore, the average fluid velocity in the wellbore, and the calculated fluid holdup in the wellbore. The formula is as follows:

[0027] in, This represents the gas production rate of the producing layer, in m³. 3 / d; This is a dimensionless calculated value of the fluid holdup in the wellbore. This refers to the cross-sectional area of ​​the wellbore, in meters (m). 2 ; It is the average velocity of the fluid inside the wellbore, in m / min. It is the difference between the gas velocity and the liquid velocity in a gas-liquid two-phase flow, and the unit is m / min.

[0028] S4, if the difference between the gas production value of the current production layer and the production value of the current production layer is within the threshold range, then the gas production value of the current production layer is used as the production value of the current production layer, and the gas production value of the next production layer is obtained, as follows: Determine whether the difference between the calculated value of the apparent velocity of the well fluid and the measured value of the apparent velocity of the well fluid is within a threshold range; determine whether the difference between the calculated value of the liquid holdup of the well fluid and the measured value of the liquid holdup of the well fluid is within a threshold range; determine whether the difference between the gas production value of the current segment and the production value of the current segment is within a threshold range. If all the above differences are within the threshold range, then the gas production value of the current segment is taken as the production value of the current segment, and the gas production value of the next segment is obtained. Otherwise, replace the production value of the producing layer with the gas production value of the producing layer in the current segment, and recalculate the apparent velocity of the well fluid in the current segment until the difference between the gas production value of the producing layer and the production value of the producing layer in the current segment is within the threshold range.

[0029] This invention addresses the current state of production logging interpretation in ultra-deep wells by iteratively optimizing calculation methods and calculating the production value of the producing layers within the production well. This can improve the accuracy of production logging interpretation and provide a scientific basis for dynamic monitoring of production logging.

[0030] Example 2: See Figure 1 This embodiment discloses a method for interpreting the reverse iterative generation profile of gas-liquid two-phase flow, as detailed below: Regarding the current status of seven-parameter production profile logging using turbine flowmeters, given the wellhead production value, gravity acceleration rate, wellbore fluid density, fluid viscosity, wellbore inner diameter, and fluid velocity profile correction coefficient, the apparent fluid velocity and fluid holdup in the wellbore are calculated using a reverse iteration method. If the apparent fluid velocity and fluid holdup values ​​obtained from the reverse iteration calculation are consistent with the measured values ​​obtained from the measuring instrument, then the production value of each producing layer is considered reasonable. To achieve the above objective, the method described in this invention includes the following steps: Step 1: Input the known parameters: wellhead gas production, wellhead water production, wellbore inner diameter D, and fluid velocity profile correction coefficient Cv; Step 2: Calculate the inner diameter PC of the wellbore; Step 3: Calculate the apparent velocity of the fluid in the wellbore to obtain the calculated value of the apparent velocity of the fluid in the wellbore; Step 4: Compare the calculated values ​​of the apparent velocity of the fluid in the wellbore with the measured values ​​of the apparent velocity of the fluid in the wellbore; Step 5: Calculate the wellbore fluid holdup value to obtain the calculated wellbore fluid holdup value; Step 6: Compare the calculated wellbore fluid holdup with the measured wellbore fluid holdup; Step 7: Iteratively calculate the gas flow rate of the production layer.

[0031] In the aforementioned steps, the measured values ​​of the apparent velocity and liquid holdup of the wellbore fluid are obtained. Steps one through four yield calculated values ​​of the apparent velocity and liquid holdup of the wellbore fluid. Computer programming is used to plot curves of these calculated values ​​at each depth point from the bottom of the well to the wellhead. Step four compares the calculated and measured values ​​of the apparent velocity; if they differ, the calculated value is iteratively calculated until the difference is within a threshold range. Step six compares the calculated and measured values ​​of the liquid holdup of the wellbore fluid; if they differ, the calculated value is iteratively calculated until the difference is within a threshold range. Finally, the gas production rate of the producing layer is determined to be the desired value.

[0032] This invention, based on the current production practices of ultra-deep gas-liquid two-phase flow wells, comprehensively considers the mathematical and logical relationships between wellhead metering data and wellbore measurement data to perform a reverse iterative interpretation of the gas-liquid two-phase flow production profile. Through production practice verification, this method calculates the gas production value of the producing layer with high accuracy. It effectively solves the problem of difficult production profile interpretation in ultra-deep gas-liquid wells, laying a scientific foundation for accurately interpreting the production values ​​of fluids in each layer of the producing layer.

[0033] Example 3: See Figure 1This embodiment discloses a method for interpreting the reverse iterative production profile of a gas-liquid two-phase flow. This method can significantly improve the accuracy of the production profile interpretation. Specifically, it includes the following steps: Step 1: Input the known parameters: wellhead gas production, wellhead water production, wellbore inner diameter D, and fluid velocity profile correction coefficient Cv.

[0034] Step 2: Calculate the inner diameter PC of the wellbore; The formula for calculating the inner diameter PC of the wellbore is as follows:

[0035] in, PC value represents the inner diameter of the wellbore, in units of ; This refers to the inner diameter of the wellbore, in mm. Note the parameters. The unit directly affects the unit of the wellbore inner diameter PC value.

[0036] Step 3: Calculate the apparent velocity of the fluid in the wellbore. The calculated value of the apparent velocity of the fluid in the wellbore is as follows:

[0037]

[0038] In the parameters of a turbine flow meter, Q represents the output value of the producing layer, measured in meters per second (m³). 3 / d; PC value represents the inner diameter of the wellbore. It is the fluid velocity profile correction coefficient, which is dimensionless and a known parameter; The apparent velocity of the fluid in the wellbore is calculated in m / min. It is the average velocity of the fluid inside the wellbore, in m / min.

[0039] Step 4: Compare the calculated values ​​of the apparent velocity of the well fluid with the measured values ​​of the apparent velocity of the well fluid to obtain the comparison results of the apparent velocity of the well fluid; The apparent velocity measurements of wellbore fluids are obtained from production logging operations. These measurements, from the bottom to the wellhead, are plotted as curve one. The apparent velocities of the wellbore fluids in each production section from the wellhead to the bottom are calculated using the formula for calculating apparent velocities, and these values ​​are plotted as curve two. The data on curves one and two are compared from the bottom to the wellhead. If the trends shown on the two curves are the same, it means that the calculated and measured apparent velocities of the wellbore fluids are consistent. Otherwise, the calculated apparent velocities are iteratively calculated until they match the measured values.

[0040] Step 5: Calculate the wellbore fluid holdup value to obtain the calculated wellbore fluid holdup value; In gas-liquid two-phase flow, the fluid typically exhibits flow patterns such as bubbly flow and slug flow. The difference between the gas velocity and the liquid velocity in gas-liquid two-phase flow is used in production logging with a continuous turbine flowmeter, and the formula for calculating the wellbore fluid holdup is as follows:

[0041]

[0042]

[0043] in, It is the difference between the gas velocity and the liquid velocity in a gas-liquid two-phase flow, and the unit is m / min; This is a calculated value of the fluid holdup in the wellbore, dimensionless; known quantity. This represents the gas production rate of the producing layer, in m³. 3 / d; This refers to the inner diameter of the well shaft, in meters (m). This refers to the cross-sectional area of ​​the wellbore, in meters (m). 2 ; It is the average velocity of the fluid inside the wellbore, in m / min.

[0044] Step 6: Compare the calculated and measured values ​​of the well fluid holdup to obtain the comparison results of the well fluid holdup. The measured wellbore fluid holdup is obtained from production logging operations. The measured values ​​from the bottom to the wellhead within the production wellbore are plotted as curve three. The calculated wellbore fluid holdup values ​​for each production section from the wellhead to the bottom are plotted as curve four. The values ​​from the bottom to the wellhead are compared. If the data on curves three and four show the same trend, it means that the calculated and measured wellbore fluid holdup values ​​match. Otherwise, the calculated wellbore fluid holdup values ​​are iteratively calculated until they match the measured values.

[0045] Step 7: Iteratively calculate the gas flow rate of the production layer.

[0046] Steps one through six yield the calculated, measured, and calculated wellbore fluid apparent velocity, fluid apparent velocity, and fluid holdup. Computer programming is used to plot the curves of these values ​​at each depth from the bottom of the well to the wellhead. Step four compares the calculated and measured values ​​of the wellbore fluid apparent velocity; if they differ, the calculated value is iteratively calculated until the difference is within a threshold range. Similarly, step six compares the calculated and measured values ​​of the wellbore fluid holdup; if they differ, the calculated value is iteratively calculated until the difference is within a threshold range. When the two values ​​are nearly identical, the gas production value of the corresponding producing layer is determined.

[0047] The present invention provides a method for interpreting the reverse iterative production profile of gas-liquid two-phase flow. Data processing is performed according to the above steps, as shown in Table 1.

[0048] Table 1. Interpretation data of the reverse iterative production profile of gas-liquid two-phase flow:

[0049] Two gas-water wells from a certain block in an oilfield were selected for gas-liquid two-phase flow measurement. The optimized calculated values ​​and measured values ​​are shown in Table 1. The maximum relative error of the calculation results is 9.70%, and the minimum is 5.10%, with an accuracy of over 90%. Compared with the traditional interpretation method's accuracy of 55%, the accuracy has been improved by 35%, representing a significant advancement and providing a scientific basis for dynamic monitoring of production logging in complex well conditions of ultra-deep wells.

[0050] Based on the above method, this invention also discloses a system for interpreting reverse iterative production profiles of gas-liquid two-phase flow, see [link to relevant documentation]. Figure 3 ,include: Wellbore fluid apparent velocity acquisition module: used to obtain the calculated value of the wellbore fluid apparent velocity based on the wellbore inner diameter PC value, fluid velocity profile correction coefficient and production value of the producing layer, and to obtain the average velocity value of the fluid inside the wellbore based on the calculated value of the wellbore fluid apparent velocity. Fluid holdup acquisition module: used to obtain the calculated value of wellbore fluid holdup based on the difference between gas velocity and liquid velocity; Gas production value acquisition module: used to obtain the gas production value of the current production layer based on the difference between gas velocity and liquid velocity, the average fluid velocity in the wellbore, and the calculated fluid holdup in the wellbore. Judgment Loop Module: Used to determine the gas production value and production value of the current producing layer. If the difference between the gas production value and the production value of the current producing layer is within the threshold range, the gas production value of the current producing layer is used as the production value of the producing layer, and the gas production value of the next producing layer is obtained. Otherwise, the gas production value of the current producing layer replaces the production value of the producing layer, and the apparent velocity calculation value of the wellbore fluid for the current producing layer is obtained again, until the difference between the gas production value and the production value of the current producing layer is within the threshold range.

[0051] The various modules of the system in this invention work together to accurately obtain the gas production value of each producing layer, which is beneficial to the accurate interpretation of gas-liquid two-phase flow production logging in ultra-deep wells.

[0052] An electronic device includes: a processor; a memory for storing computer program instructions; and steps for implementing a method for reverse iterative production profile interpretation of gas-liquid two-phase flow when executing the computer program.

[0053] A storage medium storing computer program instructions, which are loaded and executed by a processor, wherein the processor performs a method for interpreting gas-liquid two-phase flow reverse iterative production profiles.

[0054] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0055] This invention is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0056] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0057] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0058] The above content is only for illustrating the technical concept of the present invention and should not be construed as limiting the scope of protection of the present invention. Any modifications made to the technical solution based on the technical concept proposed in this invention shall fall within the scope of protection of this invention.

Claims

1. A method for interpreting gas-liquid two-phase flow profiles through reverse iterative generation, characterized in that, Includes the following steps: The apparent velocity of the fluid in the wellbore is calculated based on the wellbore inner diameter PC value, the fluid velocity profile correction coefficient, and the production value of the producing layer. The average velocity of the fluid inside the wellbore is then calculated based on the apparent velocity of the fluid in the wellbore. The wellbore fluid holdup is calculated based on the difference between gas velocity and liquid velocity. The gas production value of the current production layer is obtained based on the difference between gas velocity and liquid velocity, the average fluid velocity in the wellbore, and the calculated fluid holdup in the wellbore. If the difference between the gas production value of the current producing layer and the production value of the producing layer is within the threshold range, then the gas production value of the current producing layer is used as the production value of the producing layer, and the gas production value of the next producing layer is obtained. Otherwise, the gas production value of the current producing layer replaces the production value of the producing layer, and the apparent velocity of the wellbore fluid in the current layer is recalculated until the difference between the gas production value of the current producing layer and the production value of the producing layer is within the threshold range.

2. The method for interpreting gas-liquid two-phase flow reverse iterative generation profiles according to claim 1, characterized in that, The method for obtaining the wellbore inner diameter PC value is as follows: The wellbore inner diameter PC value is obtained based on the wellbore inner diameter using the following formula: in, PC value represents the inner diameter of the wellbore, in units of ; This is the inner diameter of the well shaft, in mm.

3. The method for interpreting gas-liquid two-phase flow reverse iterative generation profiles according to claim 1, characterized in that, The apparent velocity of the wellbore fluid is calculated based on the wellbore inner diameter (PC) value, the fluid velocity profile correction factor, and the production rate of the producing layer. The formula for calculating the apparent velocity of the wellbore fluid is as follows: in, Q is the calculated apparent velocity of the fluid in the wellbore, in m / min; Q is the production rate of the producing layer, in m³ / min. 3 / d; PC value represents the inner diameter of the wellbore. It is the fluid velocity profile correction coefficient, which is dimensionless and a known parameter; The average velocity value of the fluid inside the wellbore is obtained based on the calculated apparent velocity value of the fluid inside the wellbore. The formula for obtaining the average velocity value of the fluid inside the wellbore is as follows: in, It is the average velocity of the fluid inside the wellbore, in m / min. This is the calculated value of the apparent velocity of the fluid in the wellbore. It is the fluid velocity profile correction coefficient, which is dimensionless and a known parameter.

4. The method for interpreting gas-liquid two-phase flow reverse iterative generation profiles according to claim 1, characterized in that, The calculation of the wellbore fluid holdup based on the difference between gas velocity and liquid velocity is as follows: in, This is a dimensionless calculated value of the fluid holdup in the wellbore. It is the difference between the gas velocity and the liquid velocity in a gas-liquid two-phase flow, and the unit is m / min.

5. The method for interpreting gas-liquid two-phase flow reverse iterative generation profiles according to claim 1, characterized in that, The gas production value of the current producing layer is obtained based on the difference between gas velocity and liquid velocity, the average fluid velocity in the wellbore, and the calculated fluid holdup in the wellbore, as detailed below: The cross-sectional area of ​​the wellbore is obtained based on its inner diameter. The gas production value of the producing layer is obtained based on the difference between gas velocity and liquid velocity, the cross-sectional area of ​​the wellbore, the average velocity of the fluid in the wellbore, and the calculated fluid holdup in the wellbore.

6. The method for interpreting gas-liquid two-phase flow reverse iterative generation profiles according to claim 5, characterized in that, The gas production rate of the producing layer is obtained based on the cross-sectional area of ​​the wellbore, the average velocity of the fluid inside the wellbore, the calculated fluid holdup in the wellbore, and the difference between the gas velocity and the liquid velocity. The formula is as follows: in, This represents the gas production rate of the producing layer, in m³. 3 / d; This is a dimensionless calculated value of the fluid holdup in the wellbore. This refers to the cross-sectional area of ​​the wellbore, in meters (m). 2 ; It is the average velocity of the fluid inside the wellbore, in m / min. It is the difference between the gas velocity and the liquid velocity in a gas-liquid two-phase flow, and the unit is m / min.

7. The method for interpreting gas-liquid two-phase flow reverse iterative generation profiles according to claim 1, characterized in that, If the difference between the gas production value of the current producing layer and the production value of the producing layer is within a threshold range, then the gas production value of the current producing layer is used as the production value of the producing layer to obtain the gas production value of the next producing layer, as follows: The system determines whether the difference between the calculated and measured values ​​of the apparent velocity of the well fluid is within a threshold range, whether the difference between the calculated and measured values ​​of the liquid holdup of the well fluid is within a threshold range, and whether the difference between the gas production value and the production value of the current producing layer is within a threshold range. If all the above differences are within the threshold range, the gas production value of the current producing layer is taken as the production value of the producing layer, and the gas production value of the next producing layer is obtained.

8. A system for interpreting reverse iterative profiles of gas-liquid two-phase flow, characterized in that, include: Wellbore fluid apparent velocity acquisition module: used to obtain the calculated value of the wellbore fluid apparent velocity based on the wellbore inner diameter PC value, fluid velocity profile correction coefficient and production value of the producing layer, and to obtain the average velocity value of the fluid inside the wellbore based on the calculated value of the wellbore fluid apparent velocity. Fluid holdup acquisition module: used to obtain the calculated value of wellbore fluid holdup based on the difference between gas velocity and liquid velocity; Gas production value acquisition module: used to obtain the gas production value of the current production layer based on the difference between gas velocity and liquid velocity, the average fluid velocity in the wellbore, and the calculated fluid holdup in the wellbore. Judgment Loop Module: Used to determine the gas production value and production value of the current producing layer. If the difference between the gas production value and the production value of the current producing layer is within the threshold range, the gas production value of the current producing layer is used as the production value of the producing layer, and the gas production value of the next producing layer is obtained. Otherwise, the gas production value of the current producing layer replaces the production value of the producing layer, and the apparent velocity calculation value of the wellbore fluid for the current producing layer is obtained again, until the difference between the gas production value and the production value of the current producing layer is within the threshold range.

9. An electronic device, comprising: A processor; a memory, an electronic device for storing computer program instructions; characterized in that, when executing the computer program, it implements the steps of the gas-liquid two-phase flow reverse iterative production profile interpretation method as described in any one of claims 1-7.

10. A storage medium storing computer program instructions, characterized in that, When the computer program instructions are loaded and run by the processor, the processor executes the gas-liquid two-phase flow reverse iterative production profile interpretation method according to any one of claims 1-7.

11. A computer program product, said computer program product comprising computer instructions, characterized in that, The computer instructions instruct the computer to execute the gas-liquid two-phase flow reverse iterative generation profile interpretation method according to any one of claims 1-7.

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