Speed profile correction coefficient optimization calculation method, system, equipment and medium

Abstract

The invention provides a speed profile correction coefficient optimization calculation method, system and device and a medium. The method comprises the following steps that production logging information, turbine flowmeter instrument parameters, oil, gas and water high-pressure physical property information of a located area and a layer series and well bore structure information are collected; obtaining the ratio of the turbine blade diameter to the shaft sleeve inner diameter, the natural gas volume coefficient, the fluid density in a shaft and the shaft fluid viscosity based on the collected logging information and the well body structure information; obtaining a wellbore fluid Reynolds number based on the casing inner diameter, the fluid density, the fluid viscosity and the fluid average speed of the wellbore; and continuously iterating the speed profile correction coefficients through the relation chart of the speed profile correction coefficients and the Reynolds number of the wellbore fluid and the ratio of the diameter of the turbine blade to the inner diameter of the wellbore casing until the difference between the adjacent speed profile correction coefficients obtained through iteration is within a preset threshold value, and taking the finally obtained speed profile correction coefficient as a final correction coefficient.

Description

Technical Field

[0001] The invention relates to the field of oil and gas development, and in particular to a velocity profile correction coefficient optimization calculation method, system, equipment and medium. Background Art

[0002] Production profile logging is a commonly used logging technology in the field of oil and gas development. The turbine flow rate is the key parameter of production profile logging. Calculating the production of each perforated layer and the production of each phase in each production layer based on the turbine flow rate is an important means of diagnosing the production status of oil and gas wells.

[0003] The turbine flow measurement obtains the center flow velocity, called the apparent velocity. The velocity profile correction coefficient is needed to convert the apparent velocity into the average flow velocity for accurate calculation. Studies have shown that in multiple flows, the velocity profile distribution is relatively complex, affected by factors such as the turbine diameter of the measuring instrument, the inner diameter of the wellbore, the fluid viscosity, the fluid density, the average fluid velocity, etc. The flow type ranges from bubbly flow to annular mist flow, and the velocity profile correction coefficient varies from 0.1 to 10, which differs by nearly 100 times. In production practice, technical personnel in this field generally use 0.5 or 0.83 for calculation, or select a value between 0.5 and 1.0 for calculation, which mainly depends on personal experience. In gas-water two-phase flow, the interpretation error is relatively large. Summary of the invention

[0004] In view of the problems existing in the prior art, the present invention provides a velocity profile correction coefficient optimization calculation method, system, equipment and medium, which can accurately determine the velocity profile correction coefficient and improve the accuracy of production profile logging interpretation.

[0005] The present invention is achieved through the following technical solutions:

[0006] A velocity profile correction coefficient optimization calculation method comprises the following steps:

[0007] Collect production logging data, turbine flowmeter instrument parameters, oil, gas, water high-pressure physical property data of the region and formation, and wellbore structure information;

[0008] Based on the turbine flowmeter instrument parameters and wellbore structure information, the ratio of the turbine blade diameter to the wellbore casing inner diameter is obtained;

[0009] The gas deviation factor is obtained based on the production logging data, the natural gas volume coefficient is calculated based on the gas deviation factor, and the fluid density in the wellbore is obtained based on the natural gas volume coefficient;

[0010] The viscosity of the wellbore fluid is obtained based on the turbine flowmeter instrument parameters and the gas deviation factor;

[0011] The wellbore fluid Reynolds number is obtained based on the wellbore casing inner diameter, fluid density, fluid viscosity, and fluid average velocity. The velocity profile correction coefficient is continuously iterated through the relationship chart between the velocity profile correction coefficient and the wellbore fluid Reynolds number, as well as the ratio of the turbine blade diameter to the wellbore casing inner diameter, until the difference between adjacent velocity profile correction coefficients obtained through iteration is within a preset threshold, and the final velocity profile correction coefficient is used as the final correction coefficient.

[0012] Furthermore, the process of obtaining the ratio of the turbine blade diameter to the inner diameter of the wellbore casing based on the turbine flowmeter instrument parameters is as follows: in the turbine flowmeter instrument parameters, the turbine blade radius r and the inner diameter R of the wellbore casing are read, and the ratio of the turbine blade diameter to the inner diameter of the wellbore casing is obtained from the wellbore structure information as r / R.

[0013] Furthermore, the process of obtaining the gas deviation factor based on the production logging data, calculating the natural gas volume coefficient based on the gas deviation factor, and obtaining the fluid density in the wellbore based on the natural gas volume coefficient is as follows:

[0014] The gas deviation factor is:

[0015]

[0016] A=1.39(T pr -0.92) 0.5 -0.36T pr -0.101

[0017]

[0018] C=0.132-0.32lgT pr

[0019]

[0020] Wherein, T is the temperature value of the wellbore, unit: K, obtained from production logging data; P is the pressure value, unit: MPa, obtained from production logging data;

[0021] The natural gas volume coefficient is calculated using the gas equation for gas-liquid two-phase flow:

[0022]

[0023] Among them, the relevant symbols and unit descriptions are as follows: T is the absolute temperature value of the wellbore, unit: K, obtained from the production logging data; P is the pressure value, unit: psi, obtained from the production logging data;

[0024] The density of the fluid in the wellbore is:

[0025]

[0026] Among them, ρ air represents the density of air, ρ gsc Indicates the density of air under standard conditions, in g / cm 3 , γ g It represents the relative density of gas and is obtained from the high-pressure physical property data of oil, gas and water in the area and formation.

[0027] Furthermore, the process of obtaining the viscosity of the wellbore fluid based on the turbine flowmeter instrument parameters and the gas deviation factor is:

[0028] Wellbore fluid viscosity is a function of the gas composition, as well as the temperature and pressure of the environment.

[0029] Under high temperature conditions, the gas viscosity value decreases as the temperature increases. The viscosity of the wellbore fluid is expressed as:

[0030]

[0031] Mg=28.97×γ g

[0032] x = 3.5 + 986 / (1.8 × T) + 0.01Mg

[0033] y=2.4-0.2x

[0034]

[0035]

[0036] Where T is the temperature of the wellbore, unit: K, obtained from production logging data; P is the pressure value, unit: MPa, obtained from production logging data, μ g is the viscosity of the wellbore fluid, unit: Pa·S.

[0037] Furthermore, the process of obtaining the wellbore fluid Reynolds number based on the wellbore casing inner diameter, fluid density, fluid viscosity, and fluid average velocity is:

[0038]

[0039] Where R represents the inner diameter of the casing, unit: m; ρ g Indicates the density of the fluid, unit: g / cm 3 ;μ g The unit for expressing the viscosity of the fluid is Pa*S; The unit of average velocity of the fluid is m / s. Cv represents the initial value of the velocity profile correction coefficient, and V represents the fluid apparent velocity, which is obtained from production logging data.

[0040] Furthermore, the process of continuously iterating the velocity profile correction coefficient through the relationship chart between the velocity profile correction coefficient and the wellbore fluid Reynolds number and the ratio of the turbine blade diameter to the wellbore casing inner diameter until the difference between adjacent velocity profile correction coefficients obtained by iteration is within a preset threshold, and using the finally obtained velocity profile correction coefficient as the final correction coefficient is:

[0041] Set the velocity profile correction factor C v The initial value is usually 0.83, marked as C v 1. According to the Reynolds number N g , the velocity profile correction factor C v The relationship between the Reynolds number and the graph is obtained by looking up the value of C v Value, marked as C v 2;

[0042] Calculate C v 2 and C v 1, if it is greater than the preset threshold, C v 2 Alternative C v 1. Iterate again to get a C v 3. If C v 3 and C v 2 is still greater than the preset threshold, then C v 3 Alternative C v 2. Repeat this cycle until the adjacent velocity profile correction coefficient obtained by iteration is less than the preset threshold value, and then the last obtained velocity profile correction coefficient is used as the final correction coefficient.

[0043] Furthermore, the preset threshold is 0.001-0.002.

[0044] A velocity profile correction coefficient optimization calculation system, comprising:

[0045] The acquisition module is configured to acquire production logging data, turbine flowmeter instrument parameters, oil, gas, and water high-pressure physical property data of the region and formation, and wellbore structure information;

[0046] A first processing module is configured to obtain a ratio of a turbine blade diameter to an inner diameter of a wellbore casing based on a turbine flow meter instrument parameter and wellbore structure information;

[0047] The second processing module is configured to obtain a gas deviation factor based on production logging data, obtain a gas equation for gas-liquid two-phase flow based on the gas deviation factor to calculate a natural gas volume coefficient, and obtain a fluid density in the wellbore based on the natural gas volume coefficient;

[0048] A third processing module is configured to obtain a viscosity of the wellbore fluid based on the turbine flowmeter instrument parameter and the gas deviation factor;

[0049] The fourth processing module is configured to obtain the wellbore fluid Reynolds number based on the wellbore casing inner diameter, fluid density, fluid viscosity, and fluid average velocity; the output first processing module is configured to continuously iterate the velocity profile correction coefficient through a relationship chart between the velocity profile correction coefficient and the wellbore fluid Reynolds number, and a ratio of the turbine blade diameter to the wellbore casing inner diameter, until the difference between adjacent velocity profile correction coefficients obtained by iteration is within a preset threshold, and the final velocity profile correction coefficient is used as the final correction coefficient.

[0050] A computer device comprises a memory, a processor and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the processor implements the steps of a velocity profile correction coefficient optimization calculation method.

[0051] A computer-readable storage medium stores a computer program, which, when executed by a processor, implements the steps of a velocity profile correction coefficient optimization calculation method.

[0052] Compared with the prior art, the present invention has the following beneficial technical effects:

[0053] The present invention provides a velocity profile correction coefficient optimization calculation method, system, equipment and medium, comprising the following steps: collecting production logging data, turbine flowmeter instrument parameters, oil, gas, water high pressure physical property data of the region and layer system and wellbore structure information; obtaining the ratio of turbine blade diameter to wellbore casing inner diameter based on turbine flowmeter instrument parameters and wellbore structure information; obtaining a gas deviation factor based on production logging data, obtaining a gas equation for gas-liquid two-phase flow based on the gas deviation factor to calculate the natural gas volume coefficient, and obtaining the fluid density in the wellbore based on the natural gas volume coefficient; obtaining the wellbore fluid viscosity based on turbine flowmeter instrument parameters and gas deviation factors; obtaining the wellbore fluid based on the wellbore casing inner diameter, fluid density, fluid viscosity and fluid average velocity. Reynolds number; through the relationship chart between the velocity profile correction coefficient and the Reynolds number of the wellbore fluid, as well as the ratio of the turbine blade diameter to the inner diameter of the wellbore casing, the velocity profile correction coefficient is continuously iterated until the difference between adjacent velocity profile correction coefficients obtained through iteration is within a preset threshold, and the finally obtained velocity profile correction coefficient is used as the final correction coefficient; the present application calculates the Reynolds number, with the help of the "velocity profile correction coefficient and Reynolds number relationship chart" obtained experimentally, optimizes the iterative velocity profile correction coefficient, and accurately determines the velocity profile correction coefficient, which can improve the accuracy of the production profile logging interpretation, accurately analyze the production and output properties of each production layer, and provide a reliable basis for the characterization of the dominant channels of the gas reservoir and the analysis of the flooding law, thereby supporting the dynamic research and comprehensive management of the gas reservoir. BRIEF DESCRIPTION OF THE DRAWINGS

[0054] Figure 1It is a flow chart of a velocity profile correction coefficient optimization calculation method in an embodiment of the present invention;

[0055] Figure 2 A flow chart of a velocity profile correction coefficient optimization calculation method in an embodiment of the present invention;

[0056] Figure 3 Graph showing the relationship between velocity profile correction coefficient and Reynolds number in an embodiment of the present invention. DETAILED DESCRIPTION

[0057] The present invention is further described in detail below in conjunction with specific embodiments, which are intended to explain the present invention rather than to limit it.

[0058] In order to enable those skilled in the art to better understand the scheme of the present invention, the technical scheme in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of the present invention.

[0059] It should be noted that the terms "first", "second", etc. in the specification and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchanged where appropriate, so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions, for example, a process, method, system, product or device that includes a series of steps or units is not necessarily limited to those steps or units that are clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0060] The embodiment of the present invention provides a method for optimizing the calculation of velocity profile correction coefficients. Figure 1 and Figure 2 As shown, the following steps are included:

[0061] Collect production logging data, turbine flowmeter instrument parameters, oil, gas, water high-pressure physical property data of the region and formation, and wellbore structure information;

[0062] Based on the turbine flowmeter instrument parameters and wellbore structure information, the ratio of the turbine blade diameter to the wellbore casing inner diameter is obtained;

[0063] Based on the production logging data, the gas deviation factor is obtained, based on the gas deviation factor, the gas equation of gas-liquid two-phase flow is obtained to calculate the natural gas volume coefficient, and based on the natural gas volume coefficient, the fluid density in the wellbore is obtained;

[0064] The viscosity of the wellbore fluid is obtained based on the turbine flowmeter instrument parameters and the gas deviation factor;

[0065] The wellbore fluid Reynolds number is obtained based on the wellbore casing inner diameter, fluid density, fluid viscosity, and fluid average velocity. The velocity profile correction coefficient is continuously iterated through the relationship chart between the velocity profile correction coefficient and the wellbore fluid Reynolds number, as well as the ratio of the turbine blade diameter to the wellbore casing inner diameter, until the difference between adjacent velocity profile correction coefficients obtained through iteration is within a preset threshold, and the final velocity profile correction coefficient is used as the final correction coefficient.

[0066] Preferably, the process of obtaining the ratio of the turbine blade diameter to the inner diameter of the wellbore casing based on the turbine flowmeter instrument parameters is as follows: in the turbine flowmeter instrument parameters, the turbine blade radius r is read, and in the wellbore structure information parameters, the inner diameter R of the wellbore casing is obtained, and the ratio of the turbine blade diameter to the inner diameter of the wellbore casing is obtained by measurement by the measuring instrument as r / R.

[0067] Preferably, the process of obtaining the gas deviation factor based on production logging data, calculating the natural gas volume coefficient by obtaining the gas equation of gas-liquid two-phase flow based on the gas deviation factor, and obtaining the fluid density in the wellbore based on the natural gas volume coefficient is as follows:

[0068] The gas deviation factor is used to describe the difference between the actual behavior of the gas and the ideal gas. In this embodiment, the gas deviation factor is:

[0069]

[0070] A=1.39(T pr -0.92) 0.5 -0.36T pr -0.101

[0071]

[0072] C=0.132-0.32lgT pr

[0073]

[0074] Wherein, T is the temperature value of the wellbore, unit: K, obtained from production logging data; P is the pressure value, unit: MPa, obtained from production logging data;

[0075] The natural gas volume coefficient is calculated using the gas equation for gas-liquid two-phase flow:

[0076]

[0077] Among them, the relevant symbols and unit descriptions are as follows: T is the absolute temperature value of the wellbore, unit: K, obtained from the production logging data; P is the pressure value, unit: PSI, obtained from the production logging data;

[0078] The density of the fluid in the wellbore is:

[0079]

[0080] Among them, ρ air represents the density of air, ρ gsc Indicates the density of air under standard conditions, in g / cm 3 , rg represents the relative density of gas.

[0081] Preferably, the process of obtaining the viscosity of the wellbore fluid based on the turbine flowmeter instrument parameters and the gas deviation factor is:

[0082] Wellbore fluid viscosity is a function of the gas composition, as well as the temperature and pressure of the environment.

[0083] Under high temperature conditions, the gas viscosity value decreases as the temperature increases. The viscosity of the wellbore fluid is expressed as:

[0084]

[0085] Mg=28.97×γ g

[0086] x = 3.5 + 986 / (1.8 × T) + 0.01Mg

[0087] y=2.4-0.2x

[0088]

[0089]

[0090] Where T is the temperature of the wellbore, unit: K, obtained from production logging data; P is the pressure value, unit: MPa, obtained from production logging data, μ g is the viscosity of the wellbore fluid, unit: Pa·S.

[0091] Preferably, the process of obtaining the wellbore fluid Reynolds number based on the wellbore casing inner diameter, fluid density, fluid viscosity, and fluid average velocity is:

[0092]

[0093] Where R represents the inner diameter of the casing, unit: m; ρ gIndicates the density of the fluid, unit: g / cm 3 ;μ g The unit of viscosity of the fluid is Pa*S; The unit of average velocity of the fluid is m / s. Cv represents the initial value of the velocity profile correction coefficient, and V represents the fluid apparent velocity, which is obtained from production logging data.

[0094] Preferably, the process of continuously iterating the velocity profile correction coefficient through the relationship chart between the velocity profile correction coefficient and the Reynolds number of the wellbore fluid and the ratio of the turbine blade diameter to the inner diameter of the wellbore casing until the difference between adjacent velocity profile correction coefficients obtained by iteration is within a preset threshold, and using the finally obtained velocity profile correction coefficient as the final correction coefficient is:

[0095] Set the velocity profile correction factor C v The initial value is usually 0.83, marked as C v 1. According to the Reynolds number N g , the velocity profile correction factor C v The relationship between the diameter of the turbine blade and the inner diameter of the wellbore casing is shown in the graph. By looking up the value, a C v Value, marked as C v 2;

[0096] Calculate C v 2 and C v 1, if the difference is greater than the preset threshold, C v 2 Alternative C v 1. Iterate again to get a C v 3. If C v 3 and C v If the error between 2 is greater than the preset threshold, C v 3 Alternative C v 2. Repeat this cycle;

[0097] Until the adjacent velocity profile correction coefficient obtained by iteration is less than the preset threshold, the finally obtained velocity profile correction coefficient is used as the final correction coefficient.

[0098] It should be noted that when calculating the Reynolds number, the average speed is required, and the average speed is obtained by initial CV value * apparent speed.

[0099] Preferably, the preset threshold is 0.001-0.002.

[0100] The present invention provides a velocity profile correction coefficient optimization calculation system, comprising:

[0101] The acquisition module is configured to acquire production logging data, turbine flowmeter instrument parameters, oil, gas, and water high-pressure physical property data of the region and formation, and wellbore structure information;

[0102] A first processing module is configured to obtain a ratio of a turbine blade diameter to an inner diameter of a wellbore casing based on a turbine flow meter instrument parameter and wellbore structure information;

[0103] The second processing module is configured to obtain a gas deviation factor based on production logging data, obtain a gas equation for gas-liquid two-phase flow based on the gas deviation factor to calculate a natural gas volume coefficient, and obtain a fluid density in the wellbore based on the natural gas volume coefficient;

[0104] A third processing module is configured to obtain a viscosity of the wellbore fluid based on the turbine flowmeter instrument parameter and the gas deviation factor;

[0105] The fourth processing module is configured to obtain the wellbore fluid Reynolds number based on the wellbore casing inner diameter, fluid density, fluid viscosity, and fluid average velocity; the output first processing module is configured to continuously iterate the velocity profile correction coefficient through a relationship chart between the velocity profile correction coefficient and the wellbore fluid Reynolds number, and a ratio of the turbine blade diameter to the wellbore casing inner diameter, until the difference between adjacent velocity profile correction coefficients obtained by iteration is within a preset threshold, and the final velocity profile correction coefficient is used as the final correction coefficient.

[0106] In another embodiment of the present invention, a computer device is provided, the computer device includes a processor and a memory, the memory is used to store a computer program, the computer program includes program instructions, and the processor is used to execute the program instructions stored in the computer storage medium. The processor may be a central processing unit (CPU), or other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gates or transistor logic devices, discrete hardware components, etc., which is the computing core and control core of the terminal, which is suitable for implementing one or more instructions, and is specifically suitable for loading and executing one or more instructions in the computer storage medium to implement the corresponding method flow or corresponding function; the processor described in the embodiment of the present invention can be used for the operation of a velocity profile correction coefficient optimization calculation method.

[0107] In another embodiment of the present invention, the present invention further provides a storage medium, specifically a computer-readable storage medium (Memory), which is a memory device in a computer device for storing programs and data. It is understandable that the computer-readable storage medium here can include both the built-in storage medium in the computer device and the extended storage medium supported by the computer device. The computer-readable storage medium provides a storage space, which stores the operating system of the terminal. In addition, one or more instructions suitable for being loaded and executed by the processor are also stored in the storage space, and these instructions can be one or more computer programs (including program codes). It should be noted that the computer-readable storage medium here can be a high-speed RAM memory or a non-volatile memory, such as at least one disk memory. The processor can load and execute one or more instructions stored in the computer-readable storage medium to implement the corresponding steps of the above-mentioned embodiment in the method for optimizing the calculation of a velocity profile correction coefficient.

[0108] Those skilled in the art will appreciate that embodiments of the present invention may be provided as methods, systems, or computer program products. Therefore, the present invention may take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware. Moreover, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0109] The present invention is described with reference to flowcharts and / or block diagrams of methods, devices (systems), and computer program products according to embodiments of the present invention. It should be understood that each process and / or block in the flowchart and / or block diagram, as well as the combination of processes and / or blocks in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowchart and / or block diagram. Figure 1 A process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0110] These computer program instructions may also be stored in a computer-readable memory capable of directing a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer-readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1 A process or multiple processes and / or boxes Figure 1 A function specified in one or more boxes.

[0111] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing instructions for implementing the process in the computer or other programmable device. Figure 1 A process or multiple processes and / or boxes Figure 1 The steps for the functions specified in one or more boxes.

[0112] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit it. Although the present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or replace some or all of the technical features therein with equivalents. However, these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the embodiments of the present invention.

Claims

1. A velocity profile correction coefficient optimization calculation method, It is characterized in that The following steps are included: Collect production logging data, turbine flowmeter instrument parameters, oil, gas, water high-pressure physical property data of the region and formation, and wellbore structure information; Based on the turbine flowmeter instrument parameters and wellbore structure information, the ratio of the turbine blade diameter to the wellbore casing inner diameter is obtained; The gas deviation factor is obtained based on the production logging data, the natural gas volume coefficient is calculated based on the gas deviation factor, and the fluid density in the wellbore is obtained based on the natural gas volume coefficient; The viscosity of the wellbore fluid is obtained based on the turbine flowmeter instrument parameters and the gas deviation factor; The wellbore fluid Reynolds number is obtained based on the wellbore casing inner diameter, fluid density, fluid viscosity, and fluid average velocity. The velocity profile correction coefficient is continuously iterated through the relationship chart between the velocity profile correction coefficient and the wellbore fluid Reynolds number, as well as the ratio of the turbine blade diameter to the wellbore casing inner diameter, until the difference between adjacent velocity profile correction coefficients obtained through iteration is within a preset threshold, and the final velocity profile correction coefficient is used as the final correction coefficient.

2. According to the velocity profile correction coefficient optimization calculation method of claim 1, It is characterized in that The process of obtaining the ratio of the turbine blade diameter to the inner diameter of the wellbore casing based on the turbine flowmeter instrument parameters is as follows: in the turbine flowmeter instrument parameters, the turbine blade radius r and the inner diameter of the wellbore casing R are read, and the ratio of the turbine blade diameter to the inner diameter of the wellbore casing is obtained from the wellbore structure information as r / R.

3. According to the velocity profile correction coefficient optimization calculation method of claim 1, It is characterized in that The process of obtaining the gas deviation factor based on production logging data, calculating the natural gas volume coefficient based on the gas deviation factor, and obtaining the fluid density in the wellbore based on the natural gas volume coefficient is as follows: The gas deviation factor is: A=1.39(T pr -0.92) 0.5 -0.36T pr -0.101 C=0.132-0.32lgT pr Wherein, T is the temperature value of the wellbore, unit: K, obtained from production logging data; P is the pressure value, unit: MPa, obtained from production logging data; The natural gas volume coefficient is calculated using the gas equation for gas-liquid two-phase flow: Among them, the relevant symbols and unit descriptions are as follows: T is the absolute temperature value of the wellbore, unit: K, obtained from the production logging data; P is the pressure value, unit: psi, obtained from the production logging data; The density of the fluid in the wellbore is: Among them, ρ air represents the density of air, ρ gsc Indicates the density of air under standard conditions, in g / cm 3 , γ g It represents the relative density of gas and is obtained from the high-pressure physical property data of oil, gas and water in the area and formation.

4. According to the velocity profile correction coefficient optimization calculation method of claim 1, It is characterized in that The process of obtaining the viscosity of the wellbore fluid based on the turbine flowmeter instrument parameters and the gas deviation factor is: The viscosity of the wellbore fluid is a function of the composition of the gas, as well as the temperature and pressure of the environment. Under high temperature conditions, the gas viscosity value decreases as the temperature increases. The viscosity of the wellbore fluid is expressed as: Mg=28.97×γ g x = 3.5 + 986 / (1.8 × T) + 0.01Mg y=2.4-0.2x Where T is the temperature of the wellbore, unit: K, obtained from production logging data; P is the pressure value, unit: MPa, obtained from production logging data, μ g is the viscosity of the wellbore fluid, unit: Pa·S.

5. According to the velocity profile correction coefficient optimization calculation method of claim 1, It is characterized in that The process of obtaining the wellbore fluid Reynolds number based on the wellbore casing inner diameter, fluid density, fluid viscosity, and fluid average velocity is as follows: Where R represents the inner diameter of the casing, unit: m; ρ g Indicates the density of the fluid, unit: g / cm 3 ;μ g The unit for expressing the viscosity of the fluid is Pa*S; The unit of average velocity of the fluid is m / s. Cv represents the initial value of the velocity profile correction coefficient, and V represents the fluid apparent velocity, which is obtained from production logging data.

6. According to the velocity profile correction coefficient optimization calculation method of claim 1, It is characterized in that The process of continuously iterating the velocity profile correction coefficient through the relationship chart between the velocity profile correction coefficient and the wellbore fluid Reynolds number and the ratio of the turbine blade diameter to the wellbore casing inner diameter until the difference between adjacent velocity profile correction coefficients obtained by iteration is within a preset threshold, and taking the finally obtained velocity profile correction coefficient as the final correction coefficient is as follows: Set the velocity profile correction factor C v The initial value is usually 0.83, marked as C v 1. According to the Reynolds number N g , the velocity profile correction factor C v The relationship between the diameter of the turbine blade and the inner diameter of the wellbore casing is shown in the graph. By looking up the value, a C v Value, marked as C v 2; Calculate C v 2 and C v 1, if it is greater than the preset threshold, C v 2 Alternative C v 1. Iterate again to get a C v 3. If C v 3 and C v 2 is still greater than the preset threshold, then C v 3 Alternative C v 2. Repeat this cycle until the adjacent velocity profile correction coefficient obtained by iteration is less than the preset threshold value, and then the last obtained velocity profile correction coefficient is used as the final correction coefficient.

7. According to claim 6, a velocity profile correction coefficient optimization calculation method, It is characterized in that The preset threshold is 0.001-0.

002.

8. A velocity profile correction coefficient optimization calculation system, It is characterized in that A velocity profile correction coefficient optimization calculation method based on any one of claims 1 to 7, comprising: The acquisition module is configured to acquire production logging data, turbine flowmeter instrument parameters, oil, gas, and water high-pressure physical property data of the region and formation, and wellbore structure information; A first processing module is configured to obtain a ratio of a turbine blade diameter to an inner diameter of a wellbore casing based on a turbine flow meter instrument parameter and wellbore structure information; The second processing module is configured to obtain a gas deviation factor based on production logging data, obtain a gas equation for gas-liquid two-phase flow based on the gas deviation factor to calculate a natural gas volume coefficient, and obtain a fluid density in the wellbore based on the natural gas volume coefficient; A third processing module is configured to obtain a viscosity of the wellbore fluid based on the turbine flowmeter instrument parameter and the gas deviation factor; The fourth processing module is configured to obtain the wellbore fluid Reynolds number based on the wellbore casing inner diameter, fluid density, fluid viscosity, and fluid average velocity; the output first processing module is configured to continuously iterate the velocity profile correction coefficient through a relationship chart between the velocity profile correction coefficient and the wellbore fluid Reynolds number, and a ratio of the turbine blade diameter to the wellbore casing inner diameter, until the difference between adjacent velocity profile correction coefficients obtained by iteration is within a preset threshold, and the final velocity profile correction coefficient is used as the final correction coefficient.

9. A computer device comprising a memory, a processor and a computer program stored in the memory and executable on the processor, It is characterized in that When the processor executes the computer program, the processor implements the steps of a velocity profile correction coefficient optimization calculation method as described in any one of claims 1 to 7.

10. A computer-readable storage medium storing a computer program. It is characterized in that When the computer program is executed by a processor, the steps of the method for optimizing the calculation of the velocity profile correction coefficient as claimed in any one of claims 1 to 7 are implemented.

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