Multiphase flow phase volume fraction detection method, system and device

Abstract

The invention provides a multiphase flow phase volume fraction detection method, system and device, and belongs to the technical field of multiphase flow metering. The multiphase flow phase volume fraction detection method comprises the following steps: acquiring the flow velocity of a fluid in a flowing state, the real-time fluid liquid phase moisture content and the fluid liquid phase oil content; based on preset scale information, the flowing speed and the real-time fluid liquid-phase water content, the multiphase flow gas volume content is obtained through calculation; wherein the preset scale information comprises the magnetization vector of the pure oil fluid, the magnetization vector of the pure water fluid, the longitudinal relaxation time of the pure oil fluid and the longitudinal relaxation time of the pure water fluid; and obtaining a multiphase flow phase volume fraction detection result based on the multiphase flow gas volume content, the real-time fluid liquid phase moisture content and the fluid liquid phase oil content. The three-phase volume fraction of oil, gas and water in the fluid can be detected in real time, so that the requirement of an oil well on real-time on-line metering of the flow of each phase of the fluid is met. And the detection accuracy of the phase volume fraction of the multiphase flow is improved.

Description

Technical Field

[0001] The present invention relates to the technical field of multiphase flow metering, and in particular to a multiphase flow phase content detection method, a multiphase flow phase content detection device, a multiphase flow phase content detection system, a machine-readable storage medium and an electronic device. Background Art

[0002] At present, complex fluids containing multiple components are very common in the industrial field, and their accurate measurement has always been a major problem that plagues the industry. Taking the petroleum industry as an example, the water content of crude oil is an important indicator in the process of oil development. During secondary development, water injection development is generally adopted, which leads to higher and higher water content in the oil well output fluid, and the comprehensive water content exceeds 80%. Therefore, promoting the measurement of crude oil water content is of great significance to improving oil field production technology, formulating production plans, estimating crude oil production, and predicting the development life of oil wells. The commonly used water content measurement technology on site is to sample and let it stand for a period of time, and then read the various contents after the oil and water are separated. This method has many shortcomings: (1) low accuracy and large human influence factors; (2) low efficiency; (3) additional labor costs; (4) in most cases, the sample is directly dumped after the measurement is completed, which pollutes the environment, and for gas wells, sampling has certain safety risks. With the improvement of refined management of oil and gas reservoirs and safety and environmental protection requirements, traditional measurement methods can no longer meet the requirements, and there is an urgent need for efficient, accurate, green and safe measurement methods.

[0003] As a mainstream indoor fluid component analysis technology, magnetic resonance (MR) technology has the advantages of being non-invasive, green, environmentally friendly, efficient and accurate, and has been applied to industrial sites for online measurement of complex mixed-phase fluids. At present, the most mature application of magnetic resonance technology is still indoor static measurement, that is, the measurement is completed under the premise that the measured sample and the magnetic resonance probe remain relatively still. The reason is that the intensity of the magnetic resonance signal is very weak and can be easily drowned out by environmental noise and equipment noise. Therefore, it is necessary to measure the same sample multiple times and then accumulate the signal to improve the signal-to-noise ratio.

[0004] Different from this type of application scenario, fluid phase content measurement requires that the fluid be measured in a continuous flow state, and the measurement data reflects the real-time changes in the fluid water content. Currently, magnetic resonance flowmeters exist, but fluid phase content measurement still requires a valve structure to keep the fluid still, which cannot meet the requirements of real-time online measurement. Summary of the invention

[0005] The purpose of the embodiments of the present invention is to provide a phase flow phase content detection method, a multiphase flow phase content detection device, a multiphase flow phase content detection system, a machine-readable storage medium and an electronic device. The phase flow phase content detection method realizes real-time detection of the three-phase content of oil, gas and water in the fluid, thereby meeting the demand of oil wells for real-time online metering of the flow rate of each phase of the fluid.

[0006] In order to achieve the above-mentioned object, the first aspect of the present application provides a method for detecting phase content of a multiphase flow, comprising:

[0007] Obtain the flow velocity, real-time water content and oil content of the fluid in the liquid phase of the fluid in the flowing state;

[0008] Calculating the multiphase flow gas volume content based on preset scale information, the flow velocity and the real-time fluid liquid phase water content;

[0009] Based on the multiphase flow gas volume content, the real-time fluid liquid phase water content and the fluid liquid phase oil content, a multiphase flow phase content detection result is obtained;

[0010] Wherein, the preset scale information includes the magnetization vector of the pure oil fluid, the magnetization vector of the pure water fluid, the longitudinal relaxation time of the pure oil fluid and the longitudinal relaxation time of the pure water fluid; the preset scale information is obtained by measuring the magnetization vectors of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, and measuring the longitudinal relaxation time of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, respectively, under static conditions.

[0011] In the embodiment of the present application, the multiphase flow gas volume content is calculated based on the preset scale information, the flow velocity and the real-time fluid liquid phase water content, including:

[0012] Based on the preset scale information, the flow velocity and the real-time liquid phase water content of the fluid, the first amplitude value of the pipeline filled with liquid phase fluid is calculated under the condition of the flow velocity and the liquid phase water content of the fluid;

[0013] Get the real first amplitude value of the fluid;

[0014] Obtaining the pressure in the pipeline, and determining whether the pressure in the pipeline is less than a preset threshold;

[0015] When the pressure in the pipeline is less than a preset threshold, the multiphase flow gas volume content is calculated based on the first amplitude value of the pipeline filled with liquid phase fluid and the actual first amplitude value of the fluid.

[0016] In the embodiment of the present application, when the pressure in the pipeline is not less than a preset threshold, the multiphase flow phase content detection method further includes:

[0017] Obtain gas signal;

[0018] The gas volume content of the multiphase flow is calculated based on the first amplitude value of the pipeline filled with liquid phase fluid, the real first amplitude value of the fluid, the gas signal and the flow velocity.

[0019] In the embodiment of the present application, the calculation based on the preset scale information, flow velocity and real-time fluid liquid phase water content to obtain the first amplitude value of the pipeline filled with liquid phase fluid under the condition of the flow velocity and fluid liquid phase water content includes:

[0020] Substituting the preset scale information, flow velocity and real-time fluid liquid phase water content into the first amplitude value calculation formula, obtaining the first amplitude value of the pipeline filled with liquid phase fluid under the condition of the flow velocity and fluid liquid phase water content;

[0021] The calculation formula of the first amplitude value is:

[0022]

[0023] in, is the real-time water content of the fluid liquid phase; M water is the magnetization vector of pure water fluid; M oil is the magnetization vector of pure oil fluid; L is the effective length of the prepolarized magnet; v is the flow velocity; M liquid is the initial amplitude value when the pipeline is filled with liquid fluid; T 1,water is the longitudinal relaxation time of pure water fluid; T 1,oil is the longitudinal relaxation time of pure oil fluid.

[0024] In the embodiment of the present application, the multiphase flow gas volume content is calculated based on the first amplitude value of the pipeline filled with liquid phase fluid and the real first amplitude value of the fluid, including:

[0025] Substituting the first amplitude value of the pipeline filled with liquid phase fluid and the real first amplitude value of the fluid into the first gas volume content calculation formula to obtain the multiphase flow gas volume content;

[0026] Wherein, the calculation formula of the first gas volume content is:

[0027]

[0028] Among them, M mix is the actual first amplitude value of the fluid; M liquid is the first amplitude value when the pipeline is filled with liquid fluid; is the volume content of multiphase gas.

[0029] In the embodiment of the present application, the gas signal includes the magnetization vector and the longitudinal relaxation time when the gas is fully magnetized:

[0030] The method of calculating the multiphase flow gas volume content based on the first amplitude value of the pipeline filled with liquid phase fluid, the real first amplitude value of the fluid, the gas signal and the flow velocity includes:

[0031] Substituting the first amplitude value of the pipeline filled with liquid phase fluid, the real first amplitude value of the fluid, the flow velocity, the magnetization vector when the gas is fully magnetized, and the longitudinal relaxation time into the second gas volume content calculation formula to obtain the multiphase flow gas volume content;

[0032] Wherein, the calculation formula of the volume content of the second gas is:

[0033]

[0034] Among them, M mix is the actual first amplitude value of the fluid; M liquid is the first amplitude value when the pipeline is filled with liquid fluid; is the volume content of multiphase flow gas; L is the effective length of the prepolarization magnet; v is the flow velocity; M gas is the magnetization vector when the gas is fully magnetized; T 1,gas is the longitudinal relaxation time when the gas is fully magnetized.

[0035] The second aspect of the present application provides a multiphase flow phase content detection system, which is used to implement the above-mentioned multiphase flow phase content detection method, comprising: a magnetic resonance flowmeter, a water content meter and a calculation module, wherein the magnetic resonance flowmeter is connected in series with the water content meter, and the fluid flows through the magnetic resonance flowmeter and the water content meter in sequence;

[0036] The magnetic resonance flowmeter is used to measure the flow velocity of the fluid in a flowing state and send it to the calculation module; it is also used to measure the magnetization vector of the pure oil and pure water in the test environment when they are fully magnetized, and to measure the longitudinal relaxation time of the pure oil and pure water in the test environment when they are fully magnetized, respectively, in a magnetic resonance static state, so as to obtain scale information and send it to the calculation module;

[0037] The water content meter is used to measure the real-time water content of the fluid liquid phase and the oil content of the fluid liquid phase in the fluid flow state and send them to the calculation module;

[0038] The calculation module is used to calculate the multiphase flow gas volume content based on the scale information, flow velocity and real-time fluid liquid phase water content, and obtain the multiphase flow phase content detection result based on the multiphase flow gas volume content, real-time fluid liquid phase water content and fluid liquid phase oil content.

[0039] The third aspect of the present application provides a multiphase flow phase content detection device, comprising:

[0040] An acquisition module is used to acquire the flow velocity of the fluid in a flowing state, the real-time water content of the fluid liquid phase and the oil content of the fluid liquid phase;

[0041] A gas volume calculation module, for calculating the multiphase flow gas volume content based on preset scale information, the flow velocity and the real-time fluid liquid phase water content; wherein the preset scale information includes the magnetization vector of the pure oil fluid, the magnetization vector of the pure water fluid, the longitudinal relaxation time of the pure oil fluid and the longitudinal relaxation time of the pure water fluid; the preset scale information is obtained by measuring the magnetization vector of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, and measuring the longitudinal relaxation time of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, respectively, under static conditions;

[0042] The detection result module is used to obtain the multiphase flow phase content detection result based on the multiphase flow gas volume content, the real-time fluid liquid phase water content and the fluid liquid phase oil content.

[0043] A fourth aspect of the present application provides an electronic device, the electronic device comprising:

[0044] at least one processor;

[0045] a memory connected to the at least one processor;

[0046] The memory stores instructions that can be executed by the at least one processor, and the at least one processor implements the above-mentioned multiphase flow phase content detection method by executing the instructions stored in the memory.

[0047] A fifth aspect of the present application provides a machine-readable storage medium having instructions stored thereon, which, when executed by a processor, configures the processor to execute the above-mentioned multiphase flow phase content detection method.

[0048] Through the above technical scheme, by obtaining the flow velocity, real-time fluid liquid phase water content and fluid liquid phase oil content of the fluid in the flow state; based on the preset scale information, the flow velocity and the real-time fluid liquid phase water content, the multiphase flow gas volume content is calculated; wherein, the preset scale information includes the magnetization vector of the pure oil fluid, the magnetization vector of the pure water fluid, the longitudinal relaxation time of the pure oil fluid and the longitudinal relaxation time of the pure water fluid; the preset scale information is obtained by measuring the magnetization vector of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, and measuring the longitudinal relaxation time of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized under static conditions; finally, based on the multiphase flow gas volume content, the real-time fluid liquid phase water content and the fluid liquid phase oil content, the multiphase flow phase content detection result is obtained. Fluid phase content measurement does not require the fluid to be static, and realizes real-time detection of the three-phase content of oil, gas and water in the fluid, thereby meeting the oil well's demand for real-time online metering of each phase flow of the fluid. By measuring the magnetization vector of pure oil fluid and pure water fluid in the manifold when they are fully magnetized under static conditions, and measuring the longitudinal relaxation time of pure oil fluid and pure water fluid in the manifold when they are fully magnetized, it is possible to directly calculate when performing detection in the flow state, which is convenient for calculation. At the same time, based on the preset scale information, flow velocity and real-time fluid liquid phase water content, the calculated multiphase flow gas volume content is more accurate, which improves the accuracy of multiphase flow phase content detection.

[0049] Other features and advantages of the embodiments of the present invention will be described in detail in the subsequent detailed description. BRIEF DESCRIPTION OF THE DRAWINGS

[0050] The accompanying drawings are used to provide a further understanding of the embodiments of the present invention and constitute a part of the specification. Together with the following specific implementations, they are used to explain the embodiments of the present invention, but do not constitute a limitation on the embodiments of the present invention. In the accompanying drawings:

[0051] Figure 1 A schematic diagram of an application environment of a multiphase flow phase content detection method according to an embodiment of the present application is schematically shown;

[0052] Figure 2 A schematic diagram of a process flow of a method for detecting phase content of a multiphase flow according to an embodiment of the present application is schematically shown;

[0053] Figure 3 A schematic diagram of a multiphase flow online detection flow chart of phase content according to an embodiment of the present application is shown;

[0054] Figure 4 The structure diagram of the multiphase flow phase content flow online detection system based on magnetic resonance technology according to an embodiment of the present application is schematically shown;

[0055] Figure 5 A structural block diagram of a multiphase flow phase content detection device according to an embodiment of the present application is schematically shown;

[0056] Figure 6 The internal structure diagram of a computer device according to an embodiment of the present application is schematically shown.

[0057] Description of Reference Numerals

[0058] 410 - acquisition module; 420 - gas volume calculation module; 430 - detection result module; A01 - processor; A02 - network interface; A03 - internal memory; A04 - display screen; A05 - input device; A06 - non-volatile storage medium; B01 - operating system; B02 - computer program. DETAILED DESCRIPTION

[0059] The specific implementation of the embodiment of the present invention is described in detail below in conjunction with the accompanying drawings. It should be understood that the specific implementation described here is only used to illustrate and explain the embodiment of the present invention, and is not used to limit the embodiment of the present invention.

[0060] It should be noted that if the embodiments of the present application involve directional indications (such as up, down, left, right, front, back...), the directional indications are only used to explain the relative position relationship, movement status, etc. between the components under a certain specific posture (as shown in the accompanying drawings). If the specific posture changes, the directional indication will also change accordingly.

[0061] In addition, if there are descriptions involving "first", "second", etc. in the embodiments of the present application, the descriptions of "first", "second", etc. are only used for descriptive purposes and cannot be understood as indicating or suggesting their relative importance or implicitly indicating the number of technical features indicated. Therefore, the features defined as "first" and "second" may explicitly or implicitly include at least one of the features. In addition, the technical solutions between the various embodiments can be combined with each other, but they must be based on the ability of ordinary technicians in the field to implement them. When the combination of technical solutions is contradictory or cannot be implemented, it should be deemed that such combination of technical solutions does not exist and is not within the scope of protection required by this application.

[0062] The present application provides a method for detecting phase content of a multiphase flow, which can be applied to Figure 1In the application environment shown. Among them, the terminal 102 communicates with the server 104 through the network. The server 104 obtains the flow velocity, real-time fluid liquid phase water content and fluid liquid phase oil content of the fluid in the flow state from the terminal 102; and based on the preset scale information, the flow velocity and the real-time fluid liquid phase water content, the multiphase flow gas volume content is calculated; finally, based on the multiphase flow gas volume content, the real-time fluid liquid phase water content and the fluid liquid phase oil content, the multiphase flow phase content detection result is obtained; wherein the preset scale information includes the magnetization vector of the pure oil fluid, the magnetization vector of the pure water fluid, the longitudinal relaxation time of the pure oil fluid and the longitudinal relaxation time of the pure water fluid; the preset scale information is obtained by measuring the magnetization vector of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, and measuring the longitudinal relaxation time of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized under static conditions. The oil, gas and water phase contents in the fluid are detected in real time, thereby meeting the demand of the oil well for real-time online measurement of the flow rate of each phase of the fluid. The terminal 102 can be, but is not limited to, various personal computers, laptops, smart phones, tablet computers and portable wearable devices, and the server 104 can be implemented as an independent server or a server cluster composed of multiple servers.

[0063] Figure 2 The following schematically shows a flow chart of a method for detecting phase content of a multiphase flow according to an embodiment of the present application. Figure 1 As shown, in one embodiment of the present application, a method for detecting phase content of a multiphase flow is provided. This embodiment mainly applies the method to the above Figure 1 Taking the terminal 102 (or server 104) in FIG. 1 as an example, the following steps are included:

[0064] Step 210: Obtain the flow velocity of the fluid in the flow state, the real-time water content of the fluid liquid phase, and the oil content of the fluid liquid phase;

[0065] In this embodiment, the fluid can be passed through the magnetic resonance flowmeter probe, and the magnetic resonance flowmeter emits a spin echo magnetic resonance (Carr-Purcell-Meiboom-Gill, CPMG) pulse sequence, and the flow velocity v of the fluid is obtained from the attenuation rate. After the fluid flows out of the magnetic resonance flowmeter, it can flow into the microwave moisture analyzer to detect the moisture content and oil content of the fluid, and obtain the real-time fluid liquid phase moisture content and real-time fluid liquid phase oil content. At the same time, the microwave moisture analyzer also has a temperature and pressure data acquisition function, which can provide real-time fluid temperature and pressure changes.

[0066] Step 220: Calculate the multiphase flow gas volume content based on preset scale information, the flow velocity and the real-time fluid liquid phase water content; wherein the preset scale information includes the magnetization vector of the pure oil fluid, the magnetization vector of the pure water fluid, the longitudinal relaxation time of the pure oil fluid and the longitudinal relaxation time of the pure water fluid; the preset scale information is obtained by measuring the magnetization vectors of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, and measuring the longitudinal relaxation time of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, respectively, under static conditions.

[0067] In this embodiment, the preset scale information can be measured before the detection. Specifically, before the multiphase flow content detection, pure oil and pure water fluids that are the same as the fluid to be tested are respectively introduced into the manifold, and then the magnetization vectors M of the pure oil and pure water when they are fully magnetized are respectively measured under static conditions. water and M oil , respectively measure the longitudinal relaxation time T of pure oil and pure water 1,water and T 1,oil , for use in measurement. After obtaining the calibration information, the multiphase flow gas volume content can be further calculated, including the following steps:

[0068] First, based on the preset scale information, the flow velocity and the real-time liquid phase water content of the fluid, the first amplitude value of the pipeline filled with liquid phase fluid under the condition of the flow velocity and the liquid phase water content of the fluid is calculated;

[0069] In this embodiment, based on the fluid flow rate v measured by the magnetic resonance flowmeter and the liquid phase water content data measured by the water content analysis (i.e., the real-time liquid phase water content of the fluid), the first amplitude M of the magnetic resonance free induction decay (FID) signal when the liquid phase fluid fills the pipeline under the condition of the flow rate and water content can be derived. liquid (i.e., the first amplitude value when the pipeline is filled with liquid phase fluid). The specific derivation process may be to substitute the preset scale information, flow velocity and real-time fluid liquid phase water content into the first amplitude value calculation formula to obtain the first amplitude value when the pipeline is filled with liquid phase fluid under the condition of the flow velocity and fluid liquid phase water content.

[0070] The calculation formula of the first amplitude value is:

[0071]

[0072] in, is the real-time water content of the fluid liquid phase; M water is the magnetization vector of pure water fluid; M oil is the magnetization vector of pure oil fluid; L is the effective length of the prepolarized magnet, which can be known in advance; v is the flow velocity; Mliquid is the initial amplitude value when the pipeline is filled with liquid fluid; T 1,water is the longitudinal relaxation time of pure water fluid; T 1,oil is the longitudinal relaxation time of pure oil fluid.

[0073] Then, the real first amplitude value of the fluid is obtained;

[0074] In this embodiment, the actual first amplitude value M of the fluid can be obtained by inverting the measured echo train. mix , that is, the actual first amplitude of the fluid can be measured by a magnetic resonance flowmeter.

[0075] Then, the pressure in the pipeline is obtained, and it is determined whether the pressure in the pipeline is less than a preset threshold;

[0076] In this embodiment, the preset threshold value can be set as needed, for example, the preset threshold value is 2Mpa. The pressure in the pipeline can be measured by a water content analyzer.

[0077] Then, when the pressure in the pipeline is less than a preset threshold, the multiphase flow gas volume content is calculated based on the first amplitude value of the pipeline filled with liquid phase fluid and the actual first amplitude value of the fluid.

[0078] In this embodiment, when the pressure in the pipeline is less than a preset threshold, for example, when the pressure in the pipeline is less than 2 MPa, the gas signal cannot be directly measured by magnetic resonance due to the low gas density. The calculated first amplitude value M of the pipeline filled with liquid phase fluid can be used to obtain the gas signal. liquid Compared with the actual first amplitude value M of the measured fluid mix By comparison, we can get the gas content in the fluid Specifically, the first amplitude value of the pipeline filled with liquid phase fluid and the real first amplitude value of the fluid are substituted into the first gas volume content calculation formula to obtain the multiphase flow gas volume content;

[0079] Wherein, the calculation formula of the first gas volume content is:

[0080]

[0081] Among them, M mix is the actual first amplitude value of the fluid; M liquid is the first amplitude value when the pipeline is filled with liquid fluid; is the volume content of multiphase gas.

[0082] Accordingly, when the pressure in the pipeline is not less than a preset threshold, the multiphase flow phase content detection method further includes the following steps:

[0083] First, obtain the gas signal;

[0084] Then, the multiphase flow gas volume content is calculated based on the first amplitude value of the pipeline filled with liquid phase fluid, the real first amplitude value of the fluid, the gas signal and the flow velocity.

[0085] In this embodiment, when the pressure in the pipeline is not less than the preset threshold, taking the above example, when the pressure in the pipeline is ≥2MPa, the gas signal can be directly measured and contributes to the measured first amplitude of the fluid. Then the three-phase flow gas volume content The multiphase flow gas volume content can be obtained by substituting the first amplitude value of the pipeline filled with liquid phase fluid, the real first amplitude value of the fluid, the flow velocity, the magnetization vector when the gas is fully magnetized, and the longitudinal relaxation time into the second gas volume content calculation formula;

[0086] Wherein, the calculation formula of the volume content of the second gas is:

[0087]

[0088] Among them, M mix is the actual first amplitude value of the fluid; M liquid is the first amplitude value when the pipeline is filled with liquid fluid; is the volume content of multiphase flow gas; L is the effective length of the prepolarization magnet; v is the flow velocity; M gas is the magnetization vector when the gas is fully magnetized; T 1,gas is the longitudinal relaxation time when the gas is fully magnetized.

[0089] Step 230: obtaining a multiphase flow phase content detection result based on the multiphase flow gas volume content, the real-time fluid liquid phase water content and the fluid liquid phase oil content;

[0090] In this embodiment, after the multiphase gas volume content is calculated, the detection result is obtained by combining the measured real-time fluid liquid phase water content and fluid liquid phase oil content.

[0091] In the above implementation process, the flow velocity, real-time liquid phase water content and liquid phase oil content of the fluid in the flow state are obtained; based on the preset scale information, the flow velocity and the real-time liquid phase water content of the fluid, the multiphase flow gas volume content is calculated; wherein the preset scale information includes the magnetization vector of the pure oil fluid, the magnetization vector of the pure water fluid, the longitudinal relaxation time of the pure oil fluid and the longitudinal relaxation time of the pure water fluid; the preset scale information is obtained by measuring the magnetization vector of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, and measuring the longitudinal relaxation time of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized under static conditions; finally, based on the multiphase flow gas volume content, the real-time liquid phase water content and the liquid phase oil content of the fluid, the multiphase flow phase content detection result is obtained. Fluid phase content measurement does not require the fluid to be static, and realizes real-time detection of the three-phase content of oil, gas and water in the fluid, thereby meeting the oil well's demand for real-time online metering of each phase flow of the fluid. By measuring the magnetization vector of pure oil fluid and pure water fluid in the manifold when they are fully magnetized under static conditions, and measuring the longitudinal relaxation time of pure oil fluid and pure water fluid in the manifold when they are fully magnetized, it is possible to directly calculate when performing detection in the flow state, which is convenient for calculation. At the same time, based on the preset scale information, flow velocity and real-time fluid liquid phase water content, the calculated multiphase flow gas volume content is more accurate, which improves the accuracy of multiphase flow phase content detection.

[0092] Please see Figure 3 , Figure 3 The schematic diagram shows a multiphase flow online detection flow chart according to an embodiment of the present application. First, the fluid flow rate is detected by a magnetic resonance flowmeter, and the liquid phase water content and the liquid phase oil content of the multiphase fluid are collected by a microwave moisture meter. Then, the magnetization vectors of pure oil and pure water when fully magnetized are obtained by combining the magnetic resonance static time scale measurement to deduce the first amplitude of the magnetic resonance signal when the pipeline is full of liquid phase fluid at the current flow rate; then the actual first amplitude is obtained by reverse calculation of the measured echo string; the temperature and pressure data of the fluid in the pipeline provided by the moisture meter are used to determine whether the pressure in the pipeline is less than 2MPa. When the pressure in the pipeline is less than 2MPa, the gas phase signal cannot be directly collected, and the gas volume content can be calculated by using the first gas volume content calculation formula. When the pressure in the pipeline is greater than or equal to 2MPa, the gas phase signal can be detected, and the gas volume content can be calculated by using the second gas volume content calculation formula.

[0093] Please see Figure 4 , Figure 4The structure diagram of the multiphase flow phase content online detection system based on magnetic resonance technology according to an embodiment of the present application is schematically shown. This embodiment provides a multiphase flow phase content detection system, which is used to implement the above-mentioned multiphase flow phase content detection method, including: a magnetic resonance flowmeter, a water content meter and a calculation module, the magnetic resonance flowmeter is connected in series with the water content meter, and the fluid flows through the magnetic resonance flowmeter and the water content meter in sequence;

[0094] The magnetic resonance flowmeter is used to measure the flow velocity of the fluid in a flowing state and send it to the calculation module; it is also used to measure the magnetization vector of the pure oil and pure water in the test environment when they are fully magnetized, and to measure the longitudinal relaxation time of the pure oil and pure water in the test environment when they are fully magnetized, respectively, in a magnetic resonance static state, so as to obtain scale information and send it to the calculation module;

[0095] The water content meter is used to measure the real-time water content of the fluid liquid phase and the oil content of the fluid liquid phase in the fluid flow state and send them to the calculation module;

[0096] The calculation module is used to calculate the multiphase flow gas volume content based on the scale information, flow velocity and real-time fluid liquid phase water content, and obtain the multiphase flow phase content detection result based on the multiphase flow gas volume content, real-time fluid liquid phase water content and fluid liquid phase oil content.

[0097] In this embodiment, the water content meter can be a microwave water content meter. The magnetic resonance flowmeter probe is connected in series with the microwave water content meter. The fluid flows in from the system inlet. The fluid flow rate and the FID signal amplitude of the fluid are first measured by the magnetic resonance flowmeter probe. Then the fluid flows through the microwave water content meter to measure the water content of the liquid phase of the fluid in real time. At the same time, the microwave water content meter is equipped with a temperature and pressure sensor to collect the temperature and pressure of the fluid. Finally, the fluid signal amplitude, flow rate information, and fluid water content, oil content and other data are combined, and the volume ratio of the gas in the manifold is calculated in the calculation module to finally determine the three-phase content of the fluid, gas and water.

[0098] It should be noted that the above-mentioned calculation module can be a separate calculation platform, and the magnetic resonance flowmeter and the water content meter are connected to the calculation platform. A detection device is formed by connecting the magnetic resonance flowmeter and the water content meter in series, and the magnetic resonance flowmeter and the water content meter are connected to the calculation platform. The above-mentioned calculation module can also be a spectrometer module designed in the magnetic resonance flowmeter. The spectrometer module has an edge computing function and can calculate the volume content of multiphase flow gas. By designing a calculation module in the magnetic resonance flowmeter, the edge computing function can be realized, the system structure can be simplified, and the computing efficiency can be improved.

[0099] In the above implementation process, a magnetic resonance flowmeter, a water content meter and a calculation module are set up, the magnetic resonance flowmeter is connected in series with the water content meter, and the fluid flows through the magnetic resonance flowmeter and the water content meter in sequence; the magnetic resonance flowmeter is used to measure the flow velocity of the fluid in a flowing state and send it to the calculation module; it is also used to measure the magnetization vector of the pure oil and pure water in the test environment when they are fully magnetized, and to measure the longitudinal relaxation time of the pure oil and pure water in the test environment when they are fully magnetized, respectively, in a magnetic resonance static state, so as to obtain scale information and send it to the calculation module; the water content meter is used to measure the real-time liquid phase water content and liquid phase oil content of the fluid in a flowing state and send them to the calculation module; the calculation module is used to calculate the multiphase flow gas volume content based on the scale information, the flow velocity and the real-time liquid phase water content of the fluid, and obtain the multiphase flow phase content detection result based on the multiphase flow gas volume content, the real-time liquid phase water content and the liquid phase oil content of the fluid. This enables real-time detection of the oil, gas and water phase contents in the fluid, meeting the oil well's need for real-time online metering of the flow rates of each phase of the fluid.

[0100] Based on the same inventive concept, this embodiment provides a multiphase flow phase content detection device, please refer to Figure 5 , Figure 5 The structure block diagram of a multiphase flow phase content detection device according to an embodiment of the present application is schematically shown. The multiphase flow phase content detection device includes an acquisition module 410, a gas volume calculation module 420 and a detection result module 430, wherein:

[0101] The acquisition module 410 is used to acquire the flow velocity of the fluid in the flow state, the real-time water content of the fluid liquid phase and the oil content of the fluid liquid phase;

[0102] The gas volume calculation module 420 is used to calculate the multiphase flow gas volume content based on preset scale information, the flow velocity and the real-time fluid liquid phase water content; wherein the preset scale information includes the magnetization vector of the pure oil fluid, the magnetization vector of the pure water fluid, the longitudinal relaxation time of the pure oil fluid and the longitudinal relaxation time of the pure water fluid; the preset scale information is obtained by measuring the magnetization vector of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, and measuring the longitudinal relaxation time of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, respectively, under static conditions;

[0103] The detection result module 430 is used to obtain the multiphase flow phase content detection result based on the multiphase flow gas volume content, the real-time fluid liquid phase water content and the fluid liquid phase oil content.

[0104] The multiphase flow phase content detection device includes a processor and a memory. The acquisition module 410, gas volume calculation module 420 and detection result module 430 are all stored in the memory as program units, and the processor executes the program units stored in the memory to realize corresponding functions.

[0105] The processor includes a kernel, which retrieves the corresponding program unit from the memory. One or more kernels can be set, and the real-time detection of the oil, gas and water phase contents in the fluid can be achieved by adjusting the kernel parameters.

[0106] The memory may include non-permanent memory in a computer-readable medium, random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM, and the memory includes at least one memory chip.

[0107] An embodiment of the present invention provides a machine-readable storage medium on which a program is stored. When the program is executed by a processor, the multiphase flow phase content detection method is implemented.

[0108] An embodiment of the present invention provides a processor, which is used to run a program, wherein the multiphase flow phase content detection method is executed when the program is run.

[0109] In one embodiment, a computer device is provided. The computer device may be a terminal, and its internal structure diagram may be as follows: Figure 6 As shown. The computer device includes a processor A01, a network interface A02, a display screen A04, an input device A05 and a memory (not shown in the figure) connected via a system bus. Among them, the processor A01 of the computer device is used to provide computing and control capabilities. The memory of the computer device includes an internal memory A03 and a non-volatile storage medium A06. The non-volatile storage medium A06 stores an operating system B01 and a computer program B02. The internal memory A03 provides an environment for the operation of the operating system B01 and the computer program B02 in the non-volatile storage medium A06. The network interface A02 of the computer device is used to communicate with an external terminal through a network connection. When the computer program is executed by the processor A01, a multiphase flow phase content detection method is implemented. The display screen A04 of the computer device can be a liquid crystal display or an electronic ink display, and the input device A05 of the computer device can be a touch layer covered on the display screen, or a button, trackball or touchpad set on the computer device housing, or an external keyboard, touchpad or mouse, etc.

[0110] Those skilled in the art will understand that Figure 6The structure shown in the figure is only a block diagram of a part of the structure related to the solution of the present application, and does not constitute a limitation on the computer device to which the solution of the present application is applied. The specific computer device may include more or fewer components than those shown in the figure, or combine certain components, or have a different arrangement of components.

[0111] In one embodiment, the multiphase flow phase content detection device provided in the present application can be implemented in the form of a computer program. The computer program can be Figure 6 The computer device shown in the figure is run. The memory of the computer device can store various program modules constituting the multiphase flow phase content detection device, for example, Figure 5 The acquisition module 410, gas volume calculation module 420 and detection result module 430 are shown. The computer program composed of various program modules enables the processor to execute the steps of the multiphase flow phase content detection method of each embodiment of the present application described in this specification.

[0112] Figure 6 The computer device shown can be Figure 5 The jump code segment acquisition module 410 in the multiphase flow phase content detection device shown executes step 210. The computer device may execute step 220 through the gas volume calculation module 420. The computer device may execute step 230 through the detection result module 430.

[0113] The embodiment of the present application provides an electronic device, which includes: at least one processor; a memory connected to the at least one processor; wherein the memory stores instructions that can be executed by the at least one processor, and the at least one processor implements the above-mentioned multiphase flow phase content detection method by executing the instructions stored in the memory. When the processor executes the instructions, the following steps are implemented:

[0114] Obtain the flow velocity, real-time water content and oil content of the fluid in the liquid phase of the fluid in the flowing state;

[0115] Calculating the multiphase flow gas volume content based on preset scale information, the flow velocity and the real-time fluid liquid phase water content;

[0116] Based on the multiphase flow gas volume content, the real-time fluid liquid phase water content and the fluid liquid phase oil content, a multiphase flow phase content detection result is obtained;

[0117] Wherein, the preset scale information includes the magnetization vector of the pure oil fluid, the magnetization vector of the pure water fluid, the longitudinal relaxation time of the pure oil fluid and the longitudinal relaxation time of the pure water fluid; the preset scale information is obtained by measuring the magnetization vectors of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, and measuring the longitudinal relaxation time of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, respectively, under static conditions.

[0118] In one embodiment, the calculation of the multiphase flow gas volume content based on the preset scale information, the flow velocity and the real-time fluid liquid phase water content includes:

[0119] Based on the preset scale information, the flow velocity and the real-time liquid phase water content of the fluid, the first amplitude value of the pipeline filled with liquid phase fluid is calculated under the condition of the flow velocity and the liquid phase water content of the fluid;

[0120] Get the real first amplitude value of the fluid;

[0121] Obtaining the pressure in the pipeline, and determining whether the pressure in the pipeline is less than a preset threshold;

[0122] When the pressure in the pipeline is less than a preset threshold, the multiphase flow gas volume content is calculated based on the first amplitude value of the pipeline filled with liquid phase fluid and the actual first amplitude value of the fluid.

[0123] In one embodiment, when the pressure in the pipeline is not less than a preset threshold, the multiphase flow phase content detection method further includes:

[0124] Obtain gas signal;

[0125] The gas volume content of the multiphase flow is calculated based on the first amplitude value of the pipeline filled with liquid phase fluid, the real first amplitude value of the fluid, the gas signal and the flow velocity.

[0126] In one embodiment, the calculation based on the preset scale information, flow velocity and real-time fluid liquid phase water content to obtain the first amplitude value of the pipeline filled with liquid phase fluid under the condition of the flow velocity and fluid liquid phase water content includes:

[0127] Substituting the preset scale information, flow velocity and real-time fluid liquid phase water content into the first amplitude value calculation formula, obtaining the first amplitude value of the pipeline filled with liquid phase fluid under the condition of the flow velocity and fluid liquid phase water content;

[0128] The calculation formula of the first amplitude value is:

[0129]

[0130] in, is the real-time water content of the fluid liquid phase; Mwater is the magnetization vector of pure water fluid; M oil is the magnetization vector of pure oil fluid; L is the effective length of the prepolarized magnet; v is the flow velocity; M liquid is the initial amplitude value when the pipeline is filled with liquid fluid; T 1,water is the longitudinal relaxation time of pure water fluid; T 1,oil is the longitudinal relaxation time of pure oil fluid.

[0131] In one embodiment, the calculation of the multiphase flow gas volume content based on the first amplitude value of the pipeline filled with liquid phase fluid and the real first amplitude value of the fluid includes:

[0132] Substituting the first amplitude value of the pipeline filled with liquid phase fluid and the real first amplitude value of the fluid into the first gas volume content calculation formula to obtain the multiphase flow gas volume content;

[0133] Wherein, the calculation formula of the first gas volume content is:

[0134]

[0135] Among them, M mix is the actual first amplitude value of the fluid; M liquid is the first amplitude value when the pipeline is filled with liquid fluid; is the volume content of multiphase gas.

[0136] In one embodiment, the gas signal includes the magnetization vector and the longitudinal relaxation time when the gas is fully magnetized:

[0137] The method of calculating the multiphase flow gas volume content based on the first amplitude value of the pipeline filled with liquid phase fluid, the real first amplitude value of the fluid, the gas signal and the flow velocity includes:

[0138] Substituting the first amplitude value of the pipeline filled with liquid phase fluid, the real first amplitude value of the fluid, the flow velocity, the magnetization vector when the gas is fully magnetized, and the longitudinal relaxation time into the second gas volume content calculation formula to obtain the multiphase flow gas volume content;

[0139] Wherein, the calculation formula of the volume content of the second gas is:

[0140]

[0141] Among them, M mix is the actual first amplitude value of the fluid; M liquid is the first amplitude value when the pipeline is filled with liquid fluid; is the volume content of multiphase flow gas; L is the effective length of the prepolarization magnet; v is the flow velocity; M gas is the magnetization vector when the gas is fully magnetized; T 1,gasis the longitudinal relaxation time when the gas is fully magnetized.

[0142] Those skilled in the art will appreciate that the embodiments of the present application may be provided as methods, systems, or computer program products. Therefore, the present application may adopt the form of a complete hardware embodiment, a complete software embodiment, or an embodiment in combination with software and hardware. Moreover, the present application may adopt the form of a computer program product implemented in one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) that include computer-usable program code.

[0143] The present application is described with reference to the flowcharts and / or block diagrams of the methods, devices (systems), and computer program products according to the embodiments of the present application. It should be understood that each process and / or box in the flowchart and / or block diagram, as well as the combination of the processes and / or boxes 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 generate 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.

[0144] 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.

[0145] 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. Figure 1 A process or multiple processes and / or boxes Figure 1 The steps for the functions specified in one or more boxes.

[0146] In a typical configuration, a computing device includes one or more processors (CPU), input / output interfaces, network interfaces, and memory.

[0147] The memory may include non-permanent memory in a computer-readable medium, random access memory (RAM) and / or non-volatile memory in the form of read-only memory (ROM) or flash RAM. The memory is an example of a computer-readable medium.

[0148] Computer readable media include permanent and non-permanent, removable and non-removable media that can be implemented by any method or technology to store information. Information can be computer readable instructions, data structures, program modules or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technology, compact disk read-only memory (CD-ROM), digital versatile disk (DVD) or other optical storage, magnetic cassettes, magnetic tape disk storage or other magnetic storage devices or any other non-transmission media that can be used to store information that can be accessed by a computing device. As defined herein, computer readable media does not include temporary computer readable media (transitory media), such as modulated data signals and carrier waves.

[0149] It should also be noted that the terms "include", "comprises" or any other variations thereof are intended to cover non-exclusive inclusion, so that a process, method, commodity or device including a series of elements includes not only those elements, but also other elements not explicitly listed, or also includes elements inherent to such process, method, commodity or device. In the absence of more restrictions, the elements defined by the sentence "comprises a ..." do not exclude the existence of other identical elements in the process, method, commodity or device including the elements.

[0150] The above are only embodiments of the present application and are not intended to limit the present application. For those skilled in the art, the present application may have various changes and variations. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application should be included within the scope of the claims of the present application.

Claims

1. A method for detecting phase content of a multiphase flow, characterized in that: include: Obtain the flow velocity, real-time water content and oil content of the fluid in the liquid phase of the fluid in the flowing state; Calculating the multiphase flow gas volume content based on preset scale information, the flow velocity and the real-time fluid liquid phase water content; Based on the multiphase flow gas volume content, the real-time fluid liquid phase water content and the fluid liquid phase oil content, a multiphase flow phase content detection result is obtained; Wherein, the preset scale information includes the magnetization vector of the pure oil fluid, the magnetization vector of the pure water fluid, the longitudinal relaxation time of the pure oil fluid and the longitudinal relaxation time of the pure water fluid; the preset scale information is obtained by measuring the magnetization vectors of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, and measuring the longitudinal relaxation time of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, respectively, under static conditions.

2. The method for detecting phase content of a multiphase flow according to claim 1, characterized in that: The method of calculating the multiphase flow gas volume content based on the preset scale information, the flow velocity and the real-time fluid liquid phase water content includes: Based on the preset scale information, the flow velocity and the real-time liquid phase water content of the fluid, the first amplitude value of the pipeline filled with liquid phase fluid is calculated under the condition of the flow velocity and the liquid phase water content of the fluid; Get the real first amplitude value of the fluid; Obtaining the pressure in the pipeline, and determining whether the pressure in the pipeline is less than a preset threshold; When the pressure in the pipeline is less than a preset threshold, the multiphase flow gas volume content is calculated based on the first amplitude value of the pipeline filled with liquid phase fluid and the actual first amplitude value of the fluid.

3. The method for detecting phase content of a multiphase flow according to claim 2, characterized in that: When the pressure in the pipeline is not less than a preset threshold, the multiphase flow phase content detection method further includes: Obtain gas signal; The gas volume content of the multiphase flow is calculated based on the first amplitude value of the pipeline filled with liquid phase fluid, the real first amplitude value of the fluid, the gas signal and the flow velocity.

4. The method for detecting phase content of a multiphase flow according to claim 2, characterized in that: The method of calculating the first amplitude value of the pipeline filled with liquid phase fluid under the condition of the flow velocity and the liquid phase water content of the fluid based on the preset scale information, the flow velocity and the real-time liquid phase water content of the fluid comprises: Substituting the preset scale information, flow velocity and real-time fluid liquid phase water content into the first amplitude value calculation formula, obtaining the first amplitude value of the pipeline filled with liquid phase fluid under the condition of the flow velocity and fluid liquid phase water content; The calculation formula of the first amplitude value is: in, is the real-time water content of the fluid liquid phase; M water is the magnetization vector of pure water fluid; M oil is the magnetization vector of pure oil fluid; L is the effective length of the prepolarized magnet; v is the flow velocity; M liquid is the initial amplitude value when the pipeline is filled with liquid fluid; T 1,water is the longitudinal relaxation time of pure water fluid; T 1,oil is the longitudinal relaxation time of pure oil fluid.

5. The method for detecting phase content of a multiphase flow according to claim 2, characterized in that: The method of calculating the multiphase flow gas volume content based on the first amplitude value of the pipeline filled with liquid phase fluid and the real first amplitude value of the fluid comprises: Substituting the first amplitude value of the pipeline filled with liquid phase fluid and the real first amplitude value of the fluid into the first gas volume content calculation formula to obtain the multiphase flow gas volume content; Wherein, the calculation formula of the first gas volume content is: Among them, M mix is the actual first amplitude value of the fluid; M liquid is the first amplitude value when the pipeline is filled with liquid fluid; is the volume content of multiphase gas.

6. The method for detecting phase content of a multiphase flow according to claim 3, characterized in that: The gas signal includes the magnetization vector and the longitudinal relaxation time when the gas is fully magnetized: The method of calculating the multiphase flow gas volume content based on the first amplitude value of the pipeline filled with liquid phase fluid, the real first amplitude value of the fluid, the gas signal and the flow velocity includes: Substituting the first amplitude value of the pipeline filled with liquid phase fluid, the real first amplitude value of the fluid, the flow velocity, the magnetization vector when the gas is fully magnetized, and the longitudinal relaxation time into the second gas volume content calculation formula to obtain the multiphase flow gas volume content; Wherein, the calculation formula of the volume content of the second gas is: Among them, M mix is the actual first amplitude value of the fluid; M liquid is the first amplitude value when the pipeline is filled with liquid fluid; is the volume content of multiphase flow gas; L is the effective length of the prepolarization magnet; v is the flow velocity; M gas is the magnetization vector when the gas is fully magnetized; T 1,gas is the longitudinal relaxation time when the gas is fully magnetized.

7. A multiphase flow phase content detection system, characterized in that: A method for detecting phase content of a multiphase flow for realizing any one of claims 1 to 6, comprising: a magnetic resonance flowmeter, a water content meter and a calculation module, wherein the magnetic resonance flowmeter is connected in series with the water content meter, and the fluid flows through the magnetic resonance flowmeter and the water content meter in sequence; The magnetic resonance flowmeter is used to measure the flow velocity of the fluid in a flowing state and send it to the calculation module; it is also used to measure the magnetization vector of the pure oil and pure water in the test environment when they are fully magnetized, and to measure the longitudinal relaxation time of the pure oil and pure water in the test environment when they are fully magnetized, respectively, in a magnetic resonance static state, so as to obtain scale information and send it to the calculation module; The water content meter is used to measure the real-time water content of the fluid liquid phase and the oil content of the fluid liquid phase in the fluid flow state and send them to the calculation module; The calculation module is used to calculate the multiphase flow gas volume content based on the scale information, flow velocity and real-time fluid liquid phase water content, and obtain the multiphase flow phase content detection result based on the multiphase flow gas volume content, real-time fluid liquid phase water content and fluid liquid phase oil content.

8. A multiphase flow phase content detection device, characterized in that: include: An acquisition module is used to acquire the flow velocity of the fluid in a flowing state, the real-time water content of the fluid liquid phase and the oil content of the fluid liquid phase; A gas volume calculation module, for calculating the multiphase flow gas volume content based on preset scale information, the flow velocity and the real-time fluid liquid phase water content; wherein the preset scale information includes the magnetization vector of the pure oil fluid, the magnetization vector of the pure water fluid, the longitudinal relaxation time of the pure oil fluid and the longitudinal relaxation time of the pure water fluid; the preset scale information is obtained by measuring the magnetization vector of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, and measuring the longitudinal relaxation time of the pure oil fluid and the pure water fluid in the manifold when they are fully magnetized, respectively, under static conditions; The detection result module is used to obtain the multiphase flow phase content detection result based on the multiphase flow gas volume content, the real-time fluid liquid phase water content and the fluid liquid phase oil content.

9. An electronic device, characterized in that: The electronic device includes: at least one processor; a memory connected to the at least one processor; The memory stores instructions that can be executed by the at least one processor, and the at least one processor implements the multiphase flow phase content detection method according to any one of claims 1 to 6 by executing the instructions stored in the memory.

10. A machine-readable storage medium having instructions stored thereon, characterized in that: When the instruction is executed by a processor, the processor is configured to perform the multiphase flow phase content detection method according to any one of claims 1 to 6.

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