Gas-liquid two-phase flow split-phase flow measuring device and method for temperature and pressure correction

Abstract

The invention belongs to the technical field of gas-liquid two-phase oil and gas exploitation, particularly relates to a temperature and pressure correction gas-liquid two-phase flow split-phase flow measuring device and method, and aims to solve the problems that in the prior art, reliability is poor, and the requirements of an oil and gas field for timely understanding stratum information and controlling and managing system resources cannot be met. The device comprises a temperature transmitter and a pressure transmitter which are hermetically connected and communicated with an inlet of a pipeline and used for measuring temperature data and pressure data; the plate hole flow meter is hermetically connected and communicated with the middle part of the pipeline and is used for measuring the overall volume flow; the microwave sensor is hermetically connected and communicated with the tail end of the pipeline and is used for collecting dielectric constants. And obtaining the total flow of the two-phase fluid based on the temperature data, the pressure data and the overall volume flow. According to the invention, the microwave sensor, the differential pressure flow meter, the temperature / pressure measuring instrument and other units are reasonably designed and arranged for optimal matching, so that the accurate measurement of the heterogeneous mixed gas-liquid two-phase flow in the pipeline is realized.

Description

Background Art

[0002] During the development of gas fields, the phenomenon of increasingly serious gas field water production and gradually expanding water production range occurs, with obvious production characteristics. To improve the management level of gas wells, enhance the efficiency of drainage gas production measures, and exert the productivity of gas wells, it is crucial to accurately measure the real-time gas production and liquid production. In order to conveniently and effectively conduct high-efficiency and high-precision gas-liquid detection at the wellhead for on-site data statistics and well selection work, it is necessary to develop a device for measuring flow rate and phase fraction content that is highly reliable, has strong applicability, and ensures measurement accuracy for different wet natural gas production and gas-liquid two-phase ratios in different gas wells for use in gas field sites.

[0003] Currently, the methods of gas-liquid metering include four forms: single-phase meters, gas-liquid two-phase flow meters, separator tests, and on-line monitoring skid-mounted separators. The first two measurement technologies have lower costs but poorer accuracy; the latter two technologies have better accuracy but very high costs. As a result, in many cases on-site, well selection and production allocation are carried out by combining experience with data.

[0004] Due to the relatively high humidity of the gas produced from gas fields after a period of exploitation, traditional single-phase gas flow meters often cannot work properly or even be damaged when facing wet gas, and cannot accurately measure. Therefore, the separation method or special wet gas flow meters are generally used for wet gas metering. There are mainly three methods for metering wet natural gas: single-phase meter metering, using separators, and gas-liquid two-phase flow metering equipment metering. Among them, single-phase meter metering uses traditional single-phase flow meters (such as swirl meters) and empirical estimation, with poor reliability and unable to meet the needs of oil and gas fields for timely understanding of formation information and control and management of system resources.

[0005] The specific operation of the method using separators is to transport the gas well products to the central gas gathering station, and then conduct time-sharing rotation metering after separation by the gas-liquid separator. This method has disadvantages such as complex technology, large equipment footprint, high cost, and difficulty in accurately metering single wells. The gas-liquid two-phase flow metering equipment is a combined equipment based on instruments such as flow meters, pressure gauges, and sensors, and its measurement principle is based on two assumptions: homogeneous mixing and heterogeneous mixing of gas and liquid. The accuracy and applicable range of different equipment vary greatly. Due to the various deficiencies of the first two methods, relatively speaking, the gas-liquid two-phase flow meter is a better choice.

[0006] Based on this, the present invention proposes a device and method for measuring the separated flow rate of a gas-liquid two-phase flow with temperature and pressure correction. Summary of the Invention

[0007] In order to solve the above problems in the prior art, that is, the prior art has poor reliability and cannot meet the needs of oil and gas fields for timely understanding of formation information and control and management of system resources, the present invention proposes a device and method for measuring the separated flow rate of a gas-liquid two-phase flow with temperature and pressure correction.

[0008] The present invention provides a gas-liquid two-phase flow separate flow rate measuring device with temperature and pressure correction, comprising a microwave sensor, an orifice plate flowmeter, a pressure transmitter and a temperature transmitter;

[0009] Both the temperature transmitter and the pressure transmitter are hermetically connected to and communicate with the inlet of the pipeline, and are respectively used for measuring the temperature data and pressure data of the gas-liquid two-phase fluid in the pipeline;

[0010] The orifice plate flowmeter is hermetically connected to and communicates with the middle part of the pipeline, and the orifice plate flowmeter is used for measuring the overall volume flow rate of the gas-liquid two-phase fluid in the pipeline under working conditions;

[0011] The microwave sensor is hermetically connected to and communicates with the end of the pipeline, and the microwave sensor is used for collecting the dielectric constant.

[0012] In some preferred embodiments, the device further comprises a three-valve group and a distribution box;

[0013] Both ends of the three-valve group are respectively hermetically connected to and communicate with the pipeline, and the third end of the three-valve group is hermetically connected to and communicates with the orifice plate flowmeter, and is used for assisting the orifice plate flowmeter to measure the flow rate;

[0014] The temperature transmitter, the pressure transmitter, the orifice plate flowmeter and the microwave sensor are all electrically connected to the distribution box, and the distribution box is used for providing power.

[0015] On the other hand, the present invention provides a method for measuring the separate flow rate of gas-liquid two-phase flow with temperature and pressure correction, based on a gas-liquid two-phase flow separate flow rate measuring device with temperature and pressure correction, the method comprising:

[0016] Obtain the temperature data and the pressure data, and calculate the density data of the actual gas-phase fluid under the working condition in combination with the standard gas-phase state parameters;

[0017] Obtain the dielectric constant, and calculate the volume ratio of the liquid-phase fluid and the volume ratio of the gas-phase fluid in the gas-liquid two-phase fluid;

[0018] Calculate the mixed density of the gas-liquid two-phase fluid in combination with the volume ratio of the liquid-phase fluid and the density data;

[0019] Calculate the total gas-liquid volume flow rate based on the orifice plate differential pressure obtained by the orifice plate flowmeter and the mixed density;

[0020] Calculate the gas-phase fluid volume flow rate and the liquid-phase fluid volume flow rate under the working condition according to the total gas-liquid volume flow rate, and the volume ratio of the liquid-phase fluid and the volume ratio of the gas-phase fluid;

[0021] Calculate the gas-phase fluid volume flow rate under standard conditions by combining the gas-phase fluid volume flow rate with the density data and the density of the gas-phase fluid under standard conditions;

[0022] Calculate the total sum of the gas-phase total volume flow rate under standard conditions flowing through the temperature and pressure corrected gas-liquid two-phase flow phase separation flow rate measuring device from the start of recording to the current moment according to the gas-phase volume flow rate under standard conditions at each instant; calculate the total sum of the liquid-phase total volume flow rate flowing through the temperature and pressure corrected gas-liquid two-phase flow phase separation flow rate measuring device from the start of recording to the current moment according to the liquid-phase fluid volume flow rate at each instant.

[0023] In some preferred embodiments, the method for obtaining the density data is as follows:

[0024]

[0025] where ρ0 is the density of the gas-phase fluid under standard conditions, Z0 is the compressibility factor of the gas-phase fluid under standard conditions, Z g is the compressibility factor of the gas-phase fluid under working conditions, P0 is the standard atmospheric pressure, T0 is the absolute temperature under standard conditions, P is the pressure data, and T is the temperature data.

[0026] In some preferred embodiments, the volume fraction φ l of the liquid-phase fluid and the volume fraction φ g of the gas-phase fluid, the method for obtaining them is as follows:

[0027]

[0028] where ε c is the dielectric constant of the flowing object measured by the microwave sensor; ε g and ε l are the dielectric constants of the preset gas-phase fluid and liquid-phase fluid respectively, and the parameters with subscripts c, g, and l are the physical property parameters of the gas-liquid mixture and the gas phase and liquid phase therein.

[0029] In some preferred embodiments, the method for obtaining the mixed density is as follows:

[0030] ρ c = φ g × ρ g + φ l × ρ l ;

[0031] where ρ c is the mixed density, ρ g is the gas-phase density under working conditions, and ρ l is the liquid-phase density under working conditions.

[0032] In some preferred embodiments, the total gas-liquid volume flow rate The method for obtaining it is as follows:

[0033]

[0034] where ΔP c is the orifice plate differential pressure, is the total gas-liquid mass flow rate, and K1 and K2 are preset empirical coefficients;

[0035]

[0036] In some preferred embodiments, the volume flow rate of the gas-phase fluid under the working conditions and the volume flow rate of the liquid-phase fluid The method for obtaining them is as follows:

[0037]

[0038]

[0039] In some preferred embodiments, the volume flow rate of the gas-phase fluid under the quasi-state The method for obtaining it is as follows:

[0040]

[0041]

[0042] where is the mass flow rate of the gas-phase fluid, and the subscript m represents mass; is the volume flow rate of the gas-phase fluid under the working state, and the subscript v represents volume; with the subscript v0 is the volume flow rate of the equivalent gas converted to the standard state.

[0043] In some preferred embodiments, the sum of the total gas-phase volume flow rates and the sum of the total liquid-phase volume flow rates, the method for obtaining them is as follows:

[0044]

[0045] where f is the instrument recording frequency;

[0046]

[0047] where That is, the volume flow rate at any temperature and pressure is equal to the volume flow rate under the standard conditions.

[0048] Advantages of the present invention:

[0049] The present invention considers a method for measuring and calculating the separated-phase flow rates of gas-liquid two-phase flows with temperature and pressure correction in a gas-liquid non-uniform mixing state, involving a wide range of factors such as liquid-containing two-phase, gas-liquid non-uniform mixing, and large day-night temperature differences. The gas-liquid flow in the wellhead pipeline is very complex. By reasonably designing and arranging the optimal matching of units such as microwave sensors, differential pressure flowmeters, and temperature / pressure measuring instruments, accurate measurement of the non-uniform-phase mixed gas-liquid two-phase flow rate in the pipeline is achieved. BRIEF DESCRIPTION OF THE DRAWINGS

[0050] By reading the detailed description of the non-restrictive embodiments with reference to the following drawings, other features, objects, and advantages of the present application will become more apparent:

[0051] Figure 1 is a schematic flow chart of a method for measuring the separated-phase flow rate of gas-liquid two-phase flow with temperature and pressure correction according to the present invention;

[0052] Figure 2 is a schematic structural diagram of a device for measuring the separated-phase flow rate of gas-liquid two-phase flow with temperature and pressure correction according to the present invention;

[0053] Figure 3 is a schematic structural diagram of a computer system of a server for implementing the method, system, and device embodiments of the present application. DETAILED DESCRIPTION OF THE EMBODIMENTS

[0054] The following further describes the present application in detail with reference to the drawings and embodiments. It can be understood that the specific embodiments described herein are only for explaining the related invention and not for limiting the invention. Additionally, it should be noted that for the sake of description, only parts related to the relevant invention are shown in the drawings.

[0055] It should be noted that, without conflict, the embodiments in the present application and the features in the embodiments can be combined with each other. The following will detail the present application with reference to the drawings and embodiments.

[0056] In the first embodiment of the present invention, see Figure 2 , a device for measuring the separated-phase flow rate of gas-liquid two-phase flow with temperature and pressure correction is provided, including a microwave sensor 1, an orifice plate flowmeter 2, a pressure transmitter 4, and a temperature transmitter 5;

[0057] Both the temperature transmitter 5 and the pressure transmitter 4 are hermetically connected and communicated with the inlet of the pipeline 7, and are respectively used to measure the temperature data and pressure data of the gas-liquid phase fluid in the pipeline 7;

[0058] The orifice plate flowmeter 2 is hermetically connected and communicated with the middle of the pipeline 7, and the orifice plate flowmeter 2 is used to measure the overall volume flow rate of the gas-liquid two-phase fluid in the pipeline 7 under working conditions;

[0059] The microwave sensor 1 is hermetically connected and communicated with the end of the pipeline 7, and the microwave sensor 1 is used to collect the dielectric constant.

[0060] In this example, the wellhead gas-liquid detection in the actual natural gas field exploitation is taken as the target object. Among them, the gas-liquid flow in the wellhead pipeline is very complex, involving factors such as the non-uniform mixing of water and natural gas with a wide range and large day-night temperature difference. It is necessary to reasonably design and arrange the optimization matching of units such as flow meters and temperature / pressure measuring instruments, and combine high-precision coupling algorithms to achieve the accurate measurement of the non-homogeneous mixed gas-liquid two-phase flow in the wellhead pipeline.

[0061] Refer to Figure 2 , a temperature transmitter 5 (armored thermocouple - model WZPK-338, specification 80mm, measurement range -50°C to 500°C) is arranged at the gas inlet end of the pipeline 7, which is used to measure the temperature of the gas-liquid two-phase and convert it into an ADC signal of 4 - 20mA. At the same time, an absolute pressure transmitter 4 (model: 510A, measurement range 0 - 25MPa, measurement error less than 1%) is arranged at the gas inlet end of the pipeline 7 at the wellhead, which is used to measure the pressure of the gas-liquid two-phase and convert it into an ADC signal of 4 - 20mA for output. An orifice flow meter 2 (model: YC3051, measurement range 0 - 160KPa, measurement error less than 1%) is arranged in the middle section of the pipeline 7 at the wellhead, which is used to measure the volume flow rate of the gas-liquid two-phase and convert it into a DC signal of 4 - 20mA. A microwave sensor 1 (model: MK5158, measurement range 4 - 160m3 / h, measurement error less than 1.5%) is arranged at the end of the pipeline 7 at the wellhead, which is used to measure the volume fraction of natural gas and convert it into a DC signal of 4 - 20mA.

[0062] The electrical signals output by the temperature transmitter 5, the pressure transmitter 4, the orifice flow meter 2 and the microwave sensor 1 are sent to a 9-channel color screen recorder, and the acquisition, recording and display of multiple signals are realized simultaneously.

[0063] In the second embodiment of the present invention, a method for measuring the separated-phase flow rate of gas-liquid two-phase flow with temperature and pressure correction is proposed, based on a device for measuring the separated-phase flow rate of gas-liquid two-phase flow with temperature and pressure correction. The method includes:

[0064] Obtain the temperature data and the pressure data, and calculate the density data of the actual gas-phase fluid under the working conditions in combination with the standard gas-phase state parameters;

[0065] Obtain the dielectric constant, and calculate the volume ratio of the liquid-phase fluid and the volume ratio of the gas-phase fluid in the gas-liquid two-phase fluid;

[0066] Combine the volume ratio of the liquid-phase fluid and the density data to calculate the mixed density of the gas-liquid two-phase fluid;

[0067] Calculate the total gas-liquid volume flow rate based on the orifice plate differential pressure obtained from the orifice plate flowmeter and the mixed density.

[0068] Calculate the gas-phase fluid volume flow rate and the liquid-phase fluid volume flow rate under the operating conditions based on the total gas-liquid volume flow rate, the volume fraction of the liquid-phase fluid, and the volume fraction of the gas-phase fluid.

[0069] Combine the gas-phase fluid volume flow rate, the density data, and the density of the gas-phase fluid under standard conditions to calculate the gas-phase fluid volume flow rate under standard conditions.

[0070] Calculate the total sum of the gas-phase volume flow rate under standard conditions flowing through the temperature and pressure corrected gas-liquid two-phase flow phase separation flow measurement device from the start of recording to the current moment based on the gas-phase volume flow rate under standard conditions at each instant; calculate the total sum of the liquid-phase volume flow rate flowing through the temperature and pressure corrected gas-liquid two-phase flow phase separation flow measurement device from the start of recording to the current moment based on the liquid-phase fluid volume flow rate at each instant.

[0071] For a clearer description of a temperature and pressure corrected gas-liquid two-phase flow phase separation flow measurement method of the present invention, the following is combined with Figure 1 Expand and detail each step in the embodiments of the present invention, and each step is described in detail as follows:

[0072] Obtain the temperature data and the pressure data, and combine the standard gas-phase state parameters to calculate the density data of the actual gas-phase fluid under the operating conditions.

[0073] In the present invention, the method for obtaining the density data is:

[0074]

[0075] Among them, ρ0 is the density of the gas-phase fluid under standard conditions, Z0 is the compressibility factor of the gas-phase fluid under standard conditions, Z g is the compressibility factor of the gas-phase fluid under the working conditions, P0 is the standard atmospheric pressure of 101.325 KPa, T0 is the absolute temperature of 293.15 K under standard conditions, P is the pressure data, and T is the temperature data.

[0076] Obtain the dielectric constant, and calculate the volume fraction of the liquid-phase fluid and the volume fraction of the gas-phase fluid in the gas-liquid two-phase fluid.

[0077] In the present invention, the volume fraction φ l of the liquid-phase fluid and the volume fraction φ g of the gas-phase fluid are obtained by the following method:

[0078]

[0079] Among them, ε cis the dielectric constant of the flowing object measured by the microwave sensor 1; ε g and ε l are the dielectric constants of the preset gas-phase fluid and liquid-phase fluid, respectively, retrieved from a fluid physical property database or relevant literature; the parameters with subscripts c, g, and l are the physical property parameters of the gas-liquid mixture and the gas phase and liquid phase therein, respectively.

[0080] Combined with the volume fraction of the liquid-phase fluid and the density data, calculate the mixed density of the gas-liquid two-phase fluid;

[0081] In the present invention, the method for obtaining the mixed density is as follows:

[0082] ρ c = φ g × ρ g + φ l × ρ l ;

[0083] where ρ c is the mixed density, ρ g is the density of the gas phase under the working condition, and ρ l is the density of the liquid phase under the working condition.

[0084] Based on the orifice differential pressure obtained by the orifice flowmeter and the mixed density, calculate the total gas-liquid volume flow rate;

[0085] In the present invention, the total gas-liquid volume flow rate , the method for obtaining it is as follows:

[0086]

[0087] where ΔP c is the orifice differential pressure, is the total gas-liquid mass flow rate, and K1 and K2 are preset empirical coefficients determined by the geometric shape of the flow channel and the fluid physical property parameters;

[0088]

[0089] According to the total gas-liquid volume flow rate, and the volume fractions of the liquid-phase fluid and the gas-phase fluid, calculate the volume flow rate of the gas-phase fluid and the volume flow rate of the liquid-phase fluid under the working condition;

[0090] In the present invention, the volume flow rate of the gas-phase fluid and the volume flow rate of the liquid-phase fluid , the method for obtaining them is as follows:

[0091]

[0092]

[0093] Combine the gas-phase fluid volume flow rate with the density data and the density of the gas-phase fluid under standard conditions to calculate the gas-phase fluid volume flow rate under standard conditions;

[0094] In the present invention, the gas-phase fluid volume flow rate under the standard state The method for obtaining it is as follows:

[0095]

[0096] Calculate the total sum of the gas-phase total volume flow rate under standard conditions flowing through the temperature and pressure corrected gas-liquid two-phase flow split flow measurement device from the start of recording to the current moment according to the gas-phase volume flow rate under standard conditions at each instant; Calculate the total sum of the liquid-phase total volume flow rate flowing through the temperature and pressure corrected gas-liquid two-phase flow split flow measurement device from the start of recording to the current moment according to the liquid-phase fluid volume flow rate at each instant.

[0097] According to the natural gas density (ρ g ) after temperature and pressure correction, calculate the mass flow rate of natural gas Denoted as:

[0098]

[0099] According to the calculated mass flow rate of natural gas Look up the standard working condition of natural gas. The standard working condition density of natural gas is ρ0 = 0.7174 Kg / m 3 , calculate the volume flow rate of natural gas converted to the standard working condition Denoted as:

[0100]

[0101] Among them, is the gas-phase fluid mass flow rate, and the subscript m represents mass; is the gas-phase fluid volume flow rate under the working state, and the subscript v represents volume; with the subscript v0 is the volume flow rate of the equivalent gas converted to the standard state;

[0102] For the on-site data such as the total gas-liquid flow rate, gas-liquid volume ratio, temperature, and pressure measured and processed by the metering instrument, perform data analysis and fusion calculation, and be able to output the flow rates of natural gas and water in the gas-liquid non-uniform mixing state under different working conditions, realizing the separate measurement and statistics of the gas-liquid flow rates in the gas well.

[0103] For the acquisition frequency f and the gas-phase volume flow rate value collected at each instant and converted to the standard condition It can be accumulated to obtain the gas-phase cumulative volume flow rate converted to the standard condition from the start of recording to the current moment

[0104] In the present invention, the total sum of the gas-phase total volume flow rate and the total sum of the liquid-phase total volume flow rate are obtained by the following method:

[0105]

[0106] where f is the instrument recording frequency;

[0107]

[0108] where that is, the volume flow rate at any temperature and pressure is equal to the volume flow rate under standard conditions.

[0109] In the above embodiments, although each step is described in the above order, those skilled in the art can understand that in order to achieve the effects of this embodiment, different steps do not have to be executed in such an order. They can be executed simultaneously (in parallel) or in a reversed order, and these simple changes are all within the protection scope of the present invention.

[0110] A temperature and pressure correction gas-liquid two-phase flow phase-separated flow rate measurement system according to the third embodiment of the present invention, based on a temperature and pressure correction gas-liquid two-phase flow phase-separated flow rate measurement method according to the second embodiment, includes:

[0111] A density data calculation module configured to obtain the temperature data and the pressure data, and calculate the density data of the actual gas-phase fluid under working conditions in combination with the standard gas-phase state parameters;

[0112] A volume ratio calculation module configured to obtain the dielectric constant and calculate the volume ratio of the liquid-phase fluid and the volume ratio of the gas-phase fluid in the gas-liquid two-phase fluid;

[0113] A mixed density calculation module configured to calculate the mixed density of the gas-liquid two-phase fluid in combination with the volume ratio of the liquid-phase fluid and the density data;

[0114] A total volume flow rate calculation module configured to calculate the gas-liquid total volume flow rate based on the orifice plate differential pressure obtained by the orifice plate flowmeter and the mixed density;

[0115] A working condition volume flow rate calculation module configured to calculate the gas-phase fluid volume flow rate and the liquid-phase fluid volume flow rate under working conditions according to the gas-liquid total volume flow rate, and the volume ratio of the liquid-phase fluid and the volume ratio of the gas-phase fluid;

[0116] A standard volume flow rate calculation module configured to calculate the gas-phase fluid volume flow rate under standard conditions in combination with the gas-phase fluid volume flow rate, the density data, and the density of the gas-phase fluid under standard conditions;

[0117] An accumulation module configured to calculate the total sum of the gas-phase total volume flow rate under standard conditions flowing through the temperature and pressure corrected gas-liquid two-phase flow phase separation flow measurement device from the start of recording to the current moment according to the gas-phase volume flow rate under standard conditions at each instantaneous moment; calculate the total sum of the liquid-phase total volume flow rate flowing through the temperature and pressure corrected gas-liquid two-phase flow phase separation flow measurement device from the start of recording to the current moment according to the liquid-phase fluid volume flow rate at each instantaneous moment.

[0118] Those skilled in the art can clearly understand that for the convenience and brevity of description, the specific working process and related descriptions of the above-described system can refer to the corresponding process in the foregoing method embodiments, and will not be elaborated herein.

[0119] It should be noted that the above-described temperature and pressure corrected gas-liquid two-phase flow phase separation flow measurement system provided by the above embodiments is only illustrated by the division of the above functional modules. In practical applications, the above functions can be allocated to different functional modules according to needs, that is, the modules or steps in the embodiments of the present invention can be further decomposed or combined. For example, the modules in the above embodiments can be combined into one module, or further split into multiple sub-modules to complete all or part of the functions described above. The names of the modules and steps involved in the embodiments of the present invention are only for distinguishing each module or step, and are not regarded as an improper limitation of the present invention.

[0120] An electronic device according to a fourth embodiment of the present invention includes:

[0121] At least one processor; and

[0122] A memory communicatively connected to at least one of the processors; wherein,

[0123] The memory stores instructions executable by the processor, and the instructions are used to be executed by the processor to implement the above-described temperature and pressure corrected gas-liquid two-phase flow phase separation flow measurement method.

[0124] A computer-readable storage medium according to a fifth embodiment of the present invention, the computer-readable storage medium stores computer instructions, and the computer instructions are used to be executed by the computer to implement the above-described temperature and pressure corrected gas-liquid two-phase flow phase separation flow measurement method.

[0125] Those skilled in the art can clearly understand that for the convenience and brevity of description, the specific working process and related descriptions of the above-described storage device and processing device can refer to the corresponding process in the foregoing method embodiments, and will not be elaborated herein.

[0126] Those skilled in the art should be able to realize that the modules and method steps of each example described in combination with the embodiments disclosed herein can be implemented by electronic hardware, computer software, or a combination of both. The programs corresponding to the software modules and method steps can be placed in a random access memory (RAM), internal memory, read-only memory (ROM), electrically programmable ROM, electrically erasable programmable ROM, registers, hard disk, removable disk, CD-ROM, or any other form of storage medium well-known in the technical field. To clearly illustrate the interchangeability of electronic hardware and software, the composition and steps of each example have been generally described according to functions in the above description. Whether these functions are executed in the form of electronic hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered to exceed the scope of the present invention.

[0127] Reference is made below to Figure 3 , which shows a schematic structural diagram of a computer system of a server for implementing the method, system, and device embodiments of the present application. Figure 3 The server shown is only an example and should not impose any limitation on the functions and usage scope of the embodiments of the present application.

[0128] As Figure 3 shown, the computer system includes a central processing unit (CPU, Central Processing Unit) 301, which can perform various appropriate actions and processes according to the program stored in the read-only memory (ROM, Read Only Memory) 302 or the program loaded from the storage section 308 into the random access memory (RAM, Random Access Memory) 303. In the RAM 303, various programs and data required for system operation are also stored. The CPU 301, ROM 302, and RAM 303 are connected to each other through a bus 304. The input / output (I / O, Input / Output) interface 305 is also connected to the bus 304.

[0129] The following components are connected to the I / O interface 305: an input section 303 including a keyboard, a mouse, etc.; an output section 307 including a cathode ray tube (CRT), a liquid crystal display (LCD), etc. and a speaker, etc.; a storage section 308 including a hard disk, etc.; and a communication section 309 including a network interface card such as a LAN (Local Area Network) card, a modem, etc. The communication section 309 performs communication processing via a network such as the Internet. A drive 310 is also connected to the I / O interface 305 as required. A removable medium 311, such as a magnetic disk, an optical disk, a magneto-optical disk, a semiconductor memory, etc., is mounted on the drive 310 as required so that a computer program read therefrom is installed into the storage section 308 as required.

[0130] In particular, according to embodiments of the present disclosure, the processes described above with reference to the flowcharts can be implemented as computer software programs. For example, embodiments of the present disclosure include a computer program product that includes a computer program carried on a computer-readable medium, and the computer program includes program code for performing the methods shown in the flowcharts. In such an embodiment, the computer program can be downloaded and installed from a network through the communication section 309, and / or installed from the removable medium 311. When the computer program is executed by the central processing unit (CPU) 301, the above functions defined in the methods of the present application are performed. It should be noted that the computer-readable medium in the present application can be a computer-readable signal medium or a computer-readable storage medium or any combination of the two. The computer-readable storage medium can be, for example, but not limited to, an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any combination of the above. More specific examples of the computer-readable storage medium can include, but are not limited to: an electrical connection with one or more wires, a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the above. In the present application, the computer-readable storage medium can be any tangible medium that contains or stores a program that can be used by or in conjunction with an instruction execution system, apparatus, or device. And in the present application, the computer-readable signal medium can include a data signal propagated in a baseband or as part of a carrier wave, which carries the computer-readable program code. Such a propagated data signal can take various forms, including but not limited to electromagnetic signals, optical signals, or any suitable combination of the above. The computer-readable signal medium can also be any computer-readable medium other than the computer-readable storage medium, which can send, propagate, or transmit a program for use by or in conjunction with an instruction execution system, apparatus, or device. The program code contained on the computer-readable medium can be transmitted using any appropriate medium, including but not limited to: wireless, wire, optical cable, RF, etc., or any suitable combination of the above.

[0131] Computer program code for performing the operations of this application can be written in one or more programming languages or combinations thereof. The above programming languages include object-oriented programming languages such as Java, Smalltalk, C++, and also include conventional procedural programming languages such as the "C" language or similar programming languages. The program code can be executed entirely on the user's computer, partially on the user's computer, executed as a stand-alone software package, partially on the user's computer and partially on a remote computer, or entirely on a remote computer or server. In the case of a remote computer, the remote computer can be connected to the user's computer through any kind of network, including a local area network (LAN) or a wide area network (WAN), or it can be connected to an external computer (e.g., through the Internet using an Internet service provider).

[0132] The flowcharts and block diagrams in the accompanying drawings illustrate the possible architectures, functions, and operations of systems, methods, and computer program products according to various embodiments of this application. In this regard, each block in the flowchart or block diagram can represent a module, a program segment, or a portion of code that contains one or more executable instructions for implementing the specified logical function. It should also be noted that in some alternative implementations, the functions marked in the blocks may occur in a different order than that marked in the accompanying drawings. For example, two consecutive blocks shown may actually be executed substantially in parallel, and they may sometimes be executed in the reverse order, depending on the functions involved. It should also be noted that each block in the block diagram and / or flowchart, and combinations of blocks in the block diagram and / or flowchart, can be implemented by a dedicated hardware-based system that performs the specified functions or operations, or can be implemented by a combination of dedicated hardware and computer instructions.

[0133] The terms "first", "second", etc. are used to distinguish similar objects and not to describe or represent a particular order or sequence.

[0134] The term "comprising" or any other similar term is intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus / device that comprises a series of elements includes not only those elements but also other elements not expressly listed, or also includes elements inherent to those process, method, article, or apparatus / device.

[0135] So far, the technical solution of the present invention has been described in conjunction with the preferred embodiments shown in the accompanying drawings. However, it is easily understood by those skilled in the art that the protection scope of the present invention is obviously not limited to these specific embodiments. Without departing from the principle of the present invention, those skilled in the art can make equivalent changes or substitutions to the relevant technical features, and the technical solutions after these changes or substitutions will fall within the protection scope of the present invention.

Claims

1. A gas-liquid two-phase flow separated-phase flow rate measuring device with temperature and pressure correction, characterized in that, It includes a microwave sensor (1), an orifice flowmeter (2), a pressure transmitter (4) and a temperature transmitter (5); Both the temperature transmitter (5) and the pressure transmitter (4) are hermetically connected to and communicate with the inlet of the pipeline (7), and are respectively used to measure the temperature data and pressure data of the gas-liquid two-phase fluid in the pipeline (7); The orifice flowmeter (2) is hermetically connected to and communicates with the middle of the pipeline (7), and the orifice flowmeter (2) is used to measure the overall volume flow rate of the gas-liquid two-phase fluid in the pipeline (7) under working conditions; The microwave sensor (1) is hermetically connected to and communicates with the end of the pipeline (7), and the microwave sensor (1) is used to collect the dielectric constant.

2. The gas-liquid two-phase flow separate flow rate measuring device with temperature and pressure correction according to claim 1, wherein The device further includes a three-valve group (3) and a distribution box (6); Both ends of the three-valve group (3) are respectively hermetically connected to and communicate with the pipeline (7), and the third end of the three-valve group (3) is hermetically connected to and communicates with the orifice flowmeter (2), and is used to assist the orifice flowmeter (2) to measure the flow rate; The temperature transmitter (5), the pressure transmitter (4), the orifice flowmeter (2) and the microwave sensor (1) are all electrically connected to the distribution box (6), and the distribution box (6) is used to provide power.

3. A method for measuring the separated-phase flow rates of gas-liquid two-phase flow with temperature and pressure correction, based on the device for measuring the separated-phase flow rates of gas-liquid two-phase flow with temperature and pressure correction according to any one of claims 1-2, characterized in that, The method includes: Obtain the temperature data and the pressure data, and calculate the density data of the actual gas-phase fluid under the working condition by combining the standard gas-phase state parameters; Obtain the dielectric constant, and calculate the volume fraction of the liquid-phase fluid and the volume fraction of the gas-phase fluid in the gas-liquid two-phase fluid; Combine the volume fraction of the liquid-phase fluid and the density data to calculate the mixed density of the gas-liquid two-phase fluid; Based on the orifice plate differential pressure obtained by the orifice flowmeter and the mixed density, calculate the total gas-liquid volume flow rate; According to the total gas-liquid volume flow rate, as well as the volume fraction of the liquid-phase fluid and the volume fraction of the gas-phase fluid, calculate the gas-phase fluid volume flow rate and the liquid-phase fluid volume flow rate under the working condition; Combine the gas-phase fluid volume flow rate, the density data and the density of the gas-phase fluid under the standard state to calculate the gas-phase fluid volume flow rate under the standard state; Calculate the total sum of the gas-phase total volume flow rate under the standard condition of the gas-liquid two-phase flow split-phase flow measurement device corrected by temperature and pressure from the start of recording to the current moment according to the gas-phase volume flow rate under the standard state at each instant; Calculate the total sum of the liquid-phase total volume flow rate of the gas-liquid two-phase flow split-phase flow measurement device corrected by temperature and pressure from the start of recording to the current moment according to the liquid-phase fluid volume flow rate at each instant.

4. A gas-liquid two-phase flow phase-separated flow rate measurement method with temperature and pressure correction according to claim 3, characterized in that, The method for obtaining the density data is: Among them, ρ0 is the density of the gas-phase fluid under standard conditions, Z0 is the compressibility factor of the gas-phase fluid under standard conditions, Z g is the compressibility factor of the gas-phase fluid under operating conditions, P0 is the standard atmospheric pressure, T0 is the absolute temperature under standard conditions, P is the pressure data, and T is the temperature data.

5. A method for measuring the separated-phase flow rate of a gas-liquid two-phase flow with temperature and pressure correction according to claim 4, characterized in that The volume fraction φ of the liquid-phase fluid l and the volume fraction φ of the gas-phase fluid g , and the obtaining method thereof is as follows: where ε c is the dielectric constant of the flowing object measured by the microwave sensor (1); ε g and ε l are the dielectric constants of the preset gas-phase fluid and liquid-phase fluid respectively; the parameters with subscripts c, g, and l are the physical property parameters of the gas-liquid mixture and the gas phase and liquid phase therein.

6. A method for measuring the separated-phase flow rate of a gas-liquid two-phase flow with temperature and pressure correction according to claim 5, characterized in that The method for obtaining the mixed density is: ρ c = φ g × ρ g + φ l × ρ l ; Among them, ρ c is the mixed density, ρ g is the gas-phase density under the operating conditions, and ρ l is the liquid-phase density under the operating conditions.

7. A method for measuring the separated phase flow rate of gas-liquid two-phase flow with temperature and pressure correction according to claim 6, characterized in that, The total gas-liquid volume flow rate The method for obtaining it is as follows: where ΔP c is the pressure difference across the orifice plate, is the total mass flow rate of gas and liquid, and K1 and K2 are preset empirical coefficients; 8. A method for measuring the separated phase flow rate of gas-liquid two-phase flow with temperature and pressure correction according to claim 7, characterized in that, The volumetric flow rate of the gas-phase fluid under the described operating conditions and the volumetric flow rate of the liquid-phase fluid The method for obtaining them is as follows:

9. A method for measuring the separated phase flow rate of a gas-liquid two-phase flow with temperature and pressure correction according to claim 7, characterized in that, The volume flow rate of the gaseous fluid under the standard state The method for obtaining it is as follows: Among them, is the mass flow rate of the gas-phase fluid, and the subscript m represents mass; is the volume flow rate of the gas-phase fluid under the working condition, and the subscript v represents volume; with subscript v0 is the volume flow rate of the equivalent gas converted to the standard state.

10. A method for measuring the separated phase flow rate of gas-liquid two-phase flow with temperature and pressure correction according to claim 9, characterized in that, The total sum of the gas-phase volumetric flow rates and the total sum of the liquid-phase volumetric flow rates, and the method for obtaining the same is as follows: Wherein, f is the instrument recording frequency; Among them, that is, the volume flow rate at any temperature and pressure is equal to the volume flow rate under standard conditions.

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