Wellhead drilling fluid gas-liquid two-phase parameter measurement system and method

Abstract

The present specification relates to the technical field of oil and gas wells, and specifically discloses a wellhead drilling fluid gas-liquid two-phase parameter measurement system and method, wherein the system comprises: an inlet detection device for non-contact measurement of gas-liquid two-phase fluid at the inlet to obtain a first fluid parameter; a sampling detection device, under the condition that the gas-liquid two-phase fluid flows into the sampling pipeline of the sampling detection device, the sampling detection device samples the gas-liquid two-phase fluid to obtain a gas-liquid two-phase fluid sample, and detects the gas-liquid two-phase fluid sample to obtain a second two-phase parameter; a real-time separation detection device for splitting the gas-liquid two-phase fluid flowing through the measured pipeline, and measuring the split gas-liquid two-phase fluid to obtain a third two-phase parameter; and a data processing device for determining a two-phase parameter measurement result of the measured pipeline based on the first fluid parameter, the second two-phase parameter and the third two-phase parameter. The above scheme can improve the accuracy and efficiency of gas-liquid two-phase parameter measurement.

Description

Technical Field

[0001] This specification relates to the field of marine and onshore oil and gas well technology, and in particular to a wellhead drilling fluid gas-liquid two-phase parameter measurement system and method. Background Technology

[0002] During drilling, drilling fluid flows from the wellhead to the bottom of the well, and then circulates back to the surface through the drill pipe and the annular space within the wellbore. As the drilling fluid circulates back to the surface, it carries away materials such as rock cuttings from the bottom of the well. In this process, it may also carry gas from the formation, resulting in the drilling fluid returning to the surface being a two-phase (gas-liquid) fluid.

[0003] During drilling, the two-phase fluids returned from the drilling fluid directly reflect the actual downhole conditions, especially the pressure profile of the bottom hole fluid and whether complex conditions have occurred. This information is crucial for wellhead operations. The flow rate and accurate measurement of the gas-liquid two-phase flow are paramount and among the most frequently used parameters in drilling engineering. Timely online monitoring of parameters such as flow rate and phase content of the two-phase flow is essential for understanding reservoir dynamics, ensuring production safety, and accurately estimating production output.

[0004] However, measuring two-phase flow remains a challenging problem. The complex interactions of various factors, such as fluid properties, pipe size, and orientation, result in highly variable phase distribution and flow patterns. In liquid-solid two-phase flow, not only are solid particles and liquid fluids closely connected and mutually influencing and constraining each other during movement, but there are also interactions between solid phases and between liquid phases, further complicating measurement. The different properties of the two media lead to highly variable and complex flow processes, posing significant difficulties and challenges to practical measurements. Therefore, wellhead two-phase flow measurement remains a major technical challenge in the petroleum industry, and a satisfactory solution for gas-liquid two-phase flow measurement technology is still lacking. Although numerous research institutions both domestically and internationally have conducted extensive studies on this issue, there are few industrial instruments for online detection of two-phase flow parameters, and most testing technologies remain in the laboratory research stage. Therefore, in-depth research and application of two-phase flow parameter measurement technology remains a highly anticipated cutting-edge discipline.

[0005] There is currently no effective solution to the above problems. Summary of the Invention

[0006] This specification provides a wellhead drilling fluid gas-liquid two-phase parameter measurement system and method to solve the technical problem of difficulty in accurately measuring gas-liquid two-phase flow rate in the prior art.

[0007] This specification also provides an embodiment of a wellhead drilling fluid gas-liquid two-phase parameter measurement system, including: An inlet detection device is installed at the inlet of the gas-liquid two-phase fluid in the pipeline under test. It is used to perform non-contact measurement of the gas-liquid two-phase fluid at the inlet to obtain the first fluid parameters of the gas-liquid two-phase fluid. A sampling and testing device is installed in the middle section of the pipeline under test. When the gas-liquid two-phase fluid is introduced into the sampling pipe of the sampling and testing device, the sampling and testing device samples the gas-liquid two-phase fluid to obtain a gas-liquid two-phase fluid sample, and tests the gas-liquid two-phase fluid sample to obtain the second two-phase parameters of the gas-liquid two-phase fluid. A real-time separation detection device is installed at the rear end of the pipeline under test. It is used to split the gas-liquid two-phase fluid flowing through the pipeline under test and to measure the split gas-liquid two-phase fluid to obtain the third two-phase parameters of the gas-liquid two-phase fluid. The data processing device is communicatively connected to the inlet detection device, the sampling detection device, and the real-time separation detection device, and is used to determine the two-phase parameter measurement results of the pipeline under test based on the first fluid parameter, the second two-phase parameter, and the third two-phase parameter.

[0008] In one embodiment, the inlet detection device includes an ultrasonic flow meter and a thermometer; The ultrasonic flow meter is used for non-contact flow measurement of gas-liquid two-phase fluids to obtain the flow parameters of the gas-liquid two-phase fluids. The thermometer is used for non-contact temperature measurement of a gas-liquid two-phase fluid to obtain its temperature parameters.

[0009] In one embodiment, the sampling and detection device includes: a three-way connector, a first ball valve, a second ball valve, a first switch, a first separator, a gas mass measuring instrument, and a liquid mass measuring instrument; wherein, The tee connector is located in the middle section of the pipeline being tested; The first ball valve is disposed between the three-way connector and the first separator, and the first switch is disposed between the first ball valve and the second ball valve; the first ball valve and the second ball valve are used to open simultaneously when the gas-liquid two-phase fluid is introduced into the sampling pipe, and are also used to close simultaneously when the fluid state introduced into the sampling pipe is stable, so as to obtain a gas-liquid two-phase fluid sample; The first switch is used to open when the first ball valve and the second ball valve are closed, so that the gas-liquid two-phase fluid sample in the sampling pipeline flows into the first separator; The first separator is used to measure the mass of the incoming gas-liquid two-phase fluid sample to obtain the mass parameters of the gas-liquid two-phase fluid sample, and is also used to separate the gas-liquid two-phase fluid sample to obtain the separated gas sample and liquid sample. The gas mass measuring instrument is connected to the gas outlet of the first separator and is used to measure the mass parameters of the separated gas sample. The liquid mass measuring instrument is connected to the liquid outlet of the first separator and is used to measure the mass parameters of the separated liquid sample.

[0010] In one embodiment, the first ball valve and the second ball valve are communicatively connected to the data processing device; the data processing device is used to control the opening and closing of the first ball valve and the second ball valve to perform timed or non-timed sampling of the gas-liquid two-phase fluid.

[0011] In one embodiment, the real-time separation detection device includes: a first throttle valve, a turbine flow meter, a second separator, a gas flow meter, and a liquid flow meter; The first throttle valve is located at the rear end of the pipeline under test and is used to split the gas-liquid two-phase fluid flowing through the pipeline under test. The turbine flow meter is used to detect the flow parameters of the split gas-liquid two-phase fluid. The second separator is used to separate the gas-liquid two-phase fluid after the split; The gas flow meter is connected to the gas outlet of the second separator and is used to measure the flow parameters of the separated gas. The liquid flow meter is connected to the liquid outlet of the second separator and is used to measure the flow parameters of the separated liquid.

[0012] In one embodiment, the first throttle valve and the turbine flow meter are communicatively connected to the data processing device; The data processing device is used to control the opening degree of the first throttle valve based on the flow parameters detected by the turbine flow meter and the preset flow split percentage.

[0013] In one embodiment, the outlet of the real-time separation detection device is connected to the pipeline under test, so that the gas measured by the gas flow meter and the liquid measured by the liquid flow meter flow into the pipeline under test.

[0014] In one embodiment, the data processing device is specifically used to convert the third two-phase parameter using the first fluid parameter to obtain the converted third two-phase parameter, and is also used to calibrate the converted third two-phase parameter based on the second two-phase parameter to obtain the calibrated two-phase parameter, and is also used to fit the calibrated two-phase parameter with the changing trend of the converted third two-phase parameter to obtain the measurement result of the two-phase parameter of the pipeline under test.

[0015] This specification provides a method for measuring the gas-liquid two-phase parameters of wellhead drilling fluid, based on the wellhead drilling fluid gas-liquid two-phase parameter measurement system described in any of the above embodiments. The method includes: Obtain the first fluid parameters, second two-phase parameters, and third two-phase parameters of the gas-liquid two-phase fluid in the pipeline under test; Based on the first fluid parameter, the second two-phase parameter, and the third two-phase parameter, the measurement results of the two-phase parameter of the pipeline under test are determined.

[0016] In one embodiment, determining the two-phase parameter measurement result of the tested pipeline based on the first fluid parameter, the second two-phase parameter, and the third two-phase parameter includes: The third two-phase parameters are converted using the first fluid parameters to obtain the converted third two-phase parameters. The converted third two-phase parameters are calibrated based on the second two-phase parameters to obtain the calibrated two-phase parameters. By combining the changing trend of the converted third two-phase parameter with the calibrated two-phase parameter, the measurement results of the two-phase parameter of the pipeline under test are obtained.

[0017] This specification also provides a wellhead drilling fluid gas-liquid two-phase parameter measuring device, based on the wellhead drilling fluid gas-liquid two-phase parameter measuring system described in any of the above embodiments, the device comprising: The acquisition module is used to acquire the first fluid parameters, the second two-phase parameters, and the third two-phase parameters of the gas-liquid two-phase fluid in the pipeline under test. The determination module is used to determine the measurement results of the two-phase parameters of the pipeline under test based on the first fluid parameter, the second two-phase parameter, and the third two-phase parameter.

[0018] This specification also provides a computer device, including a processor and a memory for storing processor-executable instructions, wherein the processor executes the instructions to implement the steps of the wellhead drilling fluid gas-liquid two-phase parameter measurement method described in any of the above embodiments.

[0019] This specification also provides a computer-readable storage medium storing computer instructions that, when executed, implement the steps of the wellhead drilling fluid gas-liquid two-phase parameter measurement method described in any of the above embodiments.

[0020] In this embodiment of the specification, a wellhead drilling fluid gas-liquid two-phase parameter measurement system is provided. The system includes: an inlet detection device, a sampling detection device, a real-time separation detection device, and a data processing device. The inlet detection device can perform non-contact measurement of the gas-liquid two-phase fluid at the inlet to obtain a first fluid parameter. The sampling detection device can sample the gas-liquid two-phase fluid when it is introduced into the sampling pipe of the sampling detection device to obtain a gas-liquid two-phase fluid sample, and detect the gas-liquid two-phase fluid sample to obtain a second two-phase parameter. The real-time separation detection device is used to split the gas-liquid two-phase fluid flowing through the pipeline under test, and measure the split gas-liquid two-phase fluid to obtain a third two-phase parameter. The data processing device can determine the two-phase parameter measurement results of the pipeline under test based on the first fluid parameter, the second two-phase parameter, and the third two-phase parameter. In the above scheme, a real-time separation detection device is used to detect the fluctuations of the gas-liquid two-phase flow in real time. Through the sampling detection device, the parameters of the gas-liquid two-phase fluid can be accurately measured. By comparing and verifying the measurement results obtained by the two methods, the real-time performance and accuracy can be complemented. Therefore, it has the characteristics of real-time measurement and accurate parameters, which can effectively improve the accuracy and efficiency of gas-liquid two-phase parameter measurement. Attached Figure Description

[0021] The accompanying drawings, which are included to provide a further understanding of this specification and form part of it, do not constitute a limitation thereof. In the drawings: Figure 1 This specification shows a schematic diagram of the structure of a wellhead drilling fluid gas-liquid two-phase parameter measurement system in one embodiment; Figure 2 This specification shows a schematic diagram of the structure of a wellhead drilling fluid gas-liquid two-phase parameter measurement system in one embodiment; Figure 3 A flowchart of a method for measuring gas-liquid two-phase parameters of wellhead drilling fluid in one embodiment of this specification is shown; Figure 4 A schematic diagram of a wellhead drilling fluid gas-liquid two-phase parameter measuring device according to one embodiment of this specification is shown; Figure 5 A schematic diagram of a computer device according to one embodiment of this specification is shown.

[0022] The reference numerals in the above figures are as follows: 100. Tested pipeline; 101. Inlet detection device; 102. Sampling detection device; 103. Real-time separation detection device; 104. Data processing device; 111. Ultrasonic flow meter; 112. Thermometer; 121. T-connector; 122. First ball valve; 123. Second ball valve; 124. First switch; 125. First separator; 126. Gas mass measuring instrument; 127. Liquid mass measuring instrument; 1311. First throttle valve; 132. Turbine flow meter; 133. Second separator; 134. Gas flow meter; 135. Liquid flow meter; 1301. First pressure sensor; 1302. Second pressure sensor; 1361. Second switch; 1362. Third switch; 1363. Fourth switch; 1312. Second throttle valve. Detailed Implementation

[0023] The principles and spirit of this specification will now be described with reference to several exemplary embodiments. It should be understood that these embodiments are given merely to enable those skilled in the art to better understand and implement this specification, and are not intended to limit the scope of this specification in any way. Rather, these embodiments are provided to make this disclosure more thorough and complete, and to fully convey the scope of this disclosure to those skilled in the art.

[0024] Those skilled in the art will recognize that the embodiments described in this specification can be implemented as a system, apparatus, method, or computer program product. Therefore, the disclosure of this specification can be specifically implemented in the following forms: entirely hardware, entirely software (including firmware, resident software, microcode, etc.), or a combination of hardware and software.

[0025] This specification also provides an embodiment of a wellhead drilling fluid gas-liquid two-phase parameter measurement system. Please refer to... Figure 1 This diagram illustrates the structure of the wellhead drilling fluid two-phase parameter measurement system as described in an embodiment of this specification. Figure 1 As shown, the wellhead drilling fluid two-phase parameter measurement system may include: an inlet detection device 101, a sampling detection device 102, a real-time separation detection device 103, and a data processing device 104.

[0026] The inlet detection device 101 can be installed at the inlet position of the gas-liquid two-phase fluid in the pipeline under test 100. The inlet position can be any location within a preset distance range from the inlet of the pipeline under test 100. The inlet detection device 101 can be used to perform non-contact measurement of the gas-liquid two-phase fluid at the inlet to obtain the first fluid parameters of the gas-liquid two-phase fluid. In one embodiment, the first fluid parameters may include the flow rate, pressure, and temperature parameters of the gas-liquid two-phase fluid, etc.

[0027] Please refer to Figure 2This diagram illustrates the structure of the wellhead drilling fluid gas-liquid two-phase parameter measurement system as described in an embodiment of this specification. Figure 2 As shown, in some embodiments of this specification, the inlet detection device 101 may include an ultrasonic flow meter 111 and a thermometer 112. The ultrasonic flow meter 111 can be used for non-contact flow measurement of a gas-liquid two-phase fluid to obtain the flow parameters of the gas-liquid two-phase fluid. The thermometer 112 can be used for non-contact temperature measurement of the gas-liquid two-phase fluid to obtain the temperature parameters of the gas-liquid two-phase fluid. The ultrasonic flow meter 111 and the thermometer 112 can be communicatively connected to the data processing device 104 to send the detected flow parameters and temperature parameters to the data processing device 104.

[0028] The sampling and testing device 102 can be located in the middle section of the pipeline under test 100. In one embodiment, the middle section of the pipeline under test can be a segment of the pipeline under test whose distance from the center of the pipeline under test is within a preset distance range. In another embodiment, the pipeline under test can be divided into three segments, either uniformly or non-uniformly, with the middle segment designated as the middle section of the pipeline under test. This application does not impose any limitations on this.

[0029] When a gas-liquid two-phase fluid is introduced into the sampling pipe of the sampling and detection device 102, the device can sample the fluid to obtain a sample and then test it to obtain the second two-phase parameters. These second two-phase parameters may include both gas phase parameters and liquid phase parameters.

[0030] The real-time separation detection device 103 can be installed at the rear end of the pipeline under test 100. In one embodiment, the rear end of the pipeline under test can be a section of the pipeline under test that is within a preset distance range from the outlet of the pipeline under test. The real-time separation detection device 103 can be used to split the gas-liquid two-phase fluid flowing through the pipeline under test 100 and measure the split gas-liquid two-phase fluid to obtain the third two-phase parameters of the gas-liquid two-phase fluid. The third two-phase parameters here may include gas phase fluid parameters and liquid phase fluid parameters.

[0031] The data processing device 104 can be communicatively connected to the inlet detection device 101, the sampling detection device 102, and the real-time separation detection device 103 to obtain the first fluid parameter, the second two-phase parameter, and the third two-phase parameter. Based on the first fluid parameter, the second two-phase parameter, and the third two-phase parameter, the data processing device 104 can determine the measurement results of the two-phase parameter of the pipeline under test.

[0032] In the above embodiments, by employing a real-time separation detection device, fluctuations in the gas-liquid two-phase flow can be detected in real time. By employing a sampling detection device, parameters of the gas-liquid two-phase fluid can be accurately measured. By comparing and verifying the measurement results obtained by the two methods, real-time performance and accuracy can be complemented. Therefore, it has the characteristics of real-time measurement and accurate parameters, which can effectively improve the accuracy and efficiency of gas-liquid two-phase parameter measurement.

[0033] Please continue to refer to this. Figure 2 ,like Figure 2 As shown in some embodiments of this specification, the sampling and detection device 102 may include: a three-way connector 121, a first ball valve 122, a second ball valve 123, a first switch 124, a first separator 125, a gas mass measuring instrument 126, and a liquid mass measuring instrument 127.

[0034] The tee connector 121 can be installed in the middle section of the tested pipeline 100. The tee connector 121 can be connected to the first separator 125 through a sampling pipeline. The first separator 125 can be a rotary separator. The first ball valve 122 can be installed between the tee connector 121 and the first separator 125. The first switch 124 can be installed between the first ball valve 122 and the second ball valve 123. The first ball valve 122 and the second ball valve 123 are used to open simultaneously when the gas-liquid two-phase fluid is introduced into the sampling pipeline. The first ball valve 122 and the second ball valve 123 are also used to close simultaneously when the fluid state in the sampling pipeline is stable, thereby obtaining a gas-liquid two-phase fluid sample. The first switch 124 can be opened after the fluid state is stable and the first ball valve 122 and the second ball valve 123 are closed, allowing the gas-liquid two-phase fluid sample in the sampling pipeline to flow into the first separator 125. The first separator 125 can be used to measure the mass of the flowing gas-liquid two-phase fluid sample to obtain the mass parameters of the gas-liquid two-phase fluid sample. The first separator 125 can also be used to separate gas-liquid two-phase fluid samples to obtain separated gas and liquid samples. A gas mass measuring instrument 126 is connected to the gas outlet of the first separator 125 and is used to measure the mass parameters of the separated gas sample. A liquid mass measuring instrument 127 is connected to the liquid outlet of the first separator 125 and is used to measure the mass parameters of the separated liquid sample.

[0035] Please continue to refer to this. Figure 2 ,like Figure 2 As shown, in some embodiments of this specification, the first ball valve 122 and the second ball valve 123 can be communicatively connected to the data processing device 104. The data processing device 104 can be used to control the opening and closing of the first ball valve 122 and the second ball valve 123 to perform timed or non-timed sampling of the gas-liquid two-phase fluid.

[0036] Please continue to refer to this. Figure 2 ,like Figure 2 As shown, in some embodiments of this specification, the real-time separation and detection device 103 may include: a first throttle valve 1311, a turbine flow meter 132, a second separator 133, a gas flow meter 134, and a liquid flow meter 135. The first throttle valve 1311 may be located at the rear end of the pipeline being measured. The first throttle valve 1311 can be used to split the gas-liquid two-phase fluid flowing through the pipeline being measured. The turbine flow meter 132 can be used to detect the flow parameters of the split gas-liquid two-phase fluid. The second separator 133 can be used to separate the split gas-liquid two-phase fluid. The gas flow meter 134 is connected to the gas outlet of the second separator 133 and is used to measure the flow parameters of the separated gas. The liquid flow meter 135 is connected to the liquid outlet of the second separator 133 and is used to measure the flow parameters of the separated liquid.

[0037] Please continue to refer to this. Figure 2 ,like Figure 2 As shown in some embodiments of this specification, the outlet of the real-time separation detection device 103 can be connected to the pipeline under test 100, so that the gas measured by the gas flow meter 134 and the liquid measured by the liquid flow meter 135 flow into the pipeline under test, so that the diverted fluid merges with the mainstream fluid in the pipeline under test.

[0038] Please continue to refer to this. Figure 2 ,like Figure 2 As shown in some embodiments of this specification, the real-time separation detection device 103 may further include: a first pressure sensor 1301, a second pressure sensor 1302, a second switch 1361, a third switch 1362, a fourth switch 1363, and a second throttle valve 1312. The first pressure sensor 1301 is used to detect the pressure of the fluid flowing into the real-time separation detection device 103, and the second pressure sensor is used to detect the pressure of the fluid flowing out of the real-time separation detection device 103. The second switch 1361 is used to control whether the separated fluid flows into the second separator 133. The third switch 1362 is used to control whether the separated gas flows into the gas flow meter 134. The fourth switch 1363 can be used to control whether the separated liquid flows into the liquid flow meter 135. The second throttle valve 1312 is used to control whether the gas and liquid flowing through the gas flow meter 134 and the liquid flow meter 135 merge into the main fluid in the pipeline 100.

[0039] In some embodiments of this specification, the first throttle valve 1311 and the turbine flow meter 132 may be communicatively connected to the data processing device 104. The data processing device 104 may be used to control the opening degree of the first throttle valve based on the flow parameters detected by the turbine flow meter 132 and a preset flow split percentage. In one embodiment, the preset flow split percentage may be 3%-7%. For example, it may be set to 5%.

[0040] In one embodiment, the data processing device 104 can determine the current flow split percentage based on the flow parameters detected by the ultrasonic flow meter and the flow parameters detected by the turbine flow meter, and control the opening of the first throttle valve based on the current flow split percentage and the preset flow split percentage, so that the current flow split percentage is equal to or close to the preset flow split percentage.

[0041] In some embodiments of this specification, the data processing device 104 can be specifically used to convert the third two-phase parameters using the first fluid parameters to obtain the converted third two-phase parameters. The data processing device 104 can also be used to calibrate the converted third two-phase parameters based on the second two-phase parameters to obtain calibrated two-phase parameters. The data processing device 104 can also be used to fit the calibrated two-phase parameters to the changing trend of the converted third two-phase parameters to obtain the measurement results of the two-phase parameters of the tested pipeline.

[0042] Specifically, since the third two-phase parameter is obtained from the flow separation and detection device by measuring the split fluid, it can be converted using the first fluid parameter based on the flow separation percentage to obtain the converted third two-phase parameter. Then, because the second two-phase parameter detected by the sampling and detection device is more accurate, the converted third two-phase parameter can be calibrated based on the second two-phase parameter to obtain the calibrated two-phase parameter. Next, considering that the third two-phase parameter detected by the real-time separation and detection device can better reflect the fluctuation of the two-phase parameters, the calibrated two-phase parameter can be fitted with the changing trend of the third two-phase parameter to obtain the final two-phase parameter measurement result. By combining the sampling measurement result and the real-time separation and detection result, both efficiency and accuracy can be considered, enabling rapid and accurate two-phase parameter measurement.

[0043] The above method will be described below with reference to a specific embodiment. However, it is worth noting that this specific embodiment is only for better illustration of this specification and does not constitute an improper limitation of this specification.

[0044] To address the challenges of existing wellhead drilling fluid two-phase flow detection technologies, this specific embodiment proposes a wellhead drilling fluid gas-liquid two-phase parameter measurement system. This system may include an inlet ultrasonic detection device, a sampling detection device, a real-time separation detection device, and a data processing device.

[0045] The inlet ultrasonic detection device installs an ultrasonic flow meter at the inlet of the gas-liquid two-phase fluid to perform non-contact measurement of the fluid. A non-contact temperature sensor is installed at the downstream end of the ultrasonic flow meter to measure the temperature of the gas-liquid two-phase fluid at the inlet.

[0046] The sampling and detection device opens the first and second ball valves when the fluid to be measured is introduced into the pipeline. Once the fluid reaches a stable state, the first and second ball valves at both ends are quickly and simultaneously closed to ensure fluid isolation at both ends of the valves. After the sampled gas-liquid fluid stabilizes, this portion of the two-phase fluid is introduced into a small centrifuge, where the two phases are rapidly separated. A mass measuring instrument can be installed in the centrifuge to measure the total mass of the sampled gas-liquid two-phase fluid. The separated gas flows into a gas mass measuring instrument through the upper channel, and the separated liquid flows into a liquid mass measuring instrument through the lower channel. The gas and liquid mass parameters detected by the gas and liquid mass measuring instruments can be sent to a data processing device.

[0047] The sampling and testing device has a tee valve in the middle of the pipeline, which connects to a rotary separator via a pipeline. A ball valve is installed on the pipeline between the tee valve and the separator. The upper and lower ends of the separator are connected to a mass measuring instrument, which is connected to a data processing system via a signal line. Sampling and testing can be performed at regular intervals or manually controlled, allowing for unpredictable measurements as needed. The measured gas phase mass content is stored wiredly in the data processing device and sorted by time. The sampling and testing method involves complete gas-liquid separation of the sample after sampling, followed by separate measurement of the mass of each phase, thus converting the two-phase fluid measurement into a single-phase fluid measurement.

[0048] The real-time separation and detection device is installed at the rear end of the pipeline being monitored. A throttle valve is installed at the inlet, and the opening of the throttle valve is used to regulate the flow of the measured fluid. A pressure sensor is installed upstream of the throttle valve, and a turbine flow meter is installed downstream of the throttle valve to measure the flow rate of the separated fluid. The opening of the throttle valve is adjusted based on the measured flow rate. After the separated fluids pass through the separator, the gas enters a gas flow meter located at the upper end of the separator for measurement, and the liquid flows into a liquid flow meter located at the lower end of the separator for measurement. The flow rate of the two-phase fluid can be measured in real time through flow detection. The metered gas and liquid can then be recombined with the main fluid through the pipeline.

[0049] In this specific embodiment, a partial separation method is used in combination with a gas-liquid flow meter to detect fluctuations in the gas-liquid two-phase flow in real time. By taking samples of drilling fluid at regular or irregular intervals for separation and detection, the parameters of the gas-liquid two phases can be accurately measured. By comparing and verifying the two measurement results, real-time performance and accuracy are complemented. This method has the characteristics of real-time measurement and accurate parameters.

[0050] Please refer to Figure 2 ,like Figure 2 As shown, a wellhead drilling fluid gas-liquid two-phase parameter measurement system mainly includes an inlet detection device 101, a sampling detection device 102, a real-time separation detection device 103, and a data processing device 104.

[0051] In implementation, an ultrasonic flow meter 111 is installed at the inlet of the gas-liquid two-phase fluid to perform non-contact measurement of the inlet gas-liquid two-phase fluid. A non-contact temperature sensor 112 is used to measure the temperature of the gas-liquid two-phase fluid at the inlet. The sampling and detection device 102 opens the first ball valve 122 and the second ball valve 123 after the fluid has stabilized, and then quickly and simultaneously closes both the upper and lower ends of the first ball valve 122 and the second ball valve 123. The first switch 124 is then opened, allowing this portion of the gas-liquid two-phase fluid to be introduced into the first separator 125. The first separator 125 rapidly separates the two phases in the gas-liquid two-phase fluid. A mass measuring instrument is installed in the first separator 125 to measure the total mass of the sampled gas-liquid two-phase fluid. The separated gas flows into the gas mass measuring instrument 126 through the upper channel; the separated liquid flows into the liquid mass measuring instrument 127 through the lower channel. The gas mass measuring instrument 126 and the liquid mass measuring instrument 127 can transmit the obtained data to the data processing device 104 through signal lines.

[0052] The real-time separation detection device 103 adjusts the flow of the measured fluid by regulating the opening of the first throttle valve 1311. The turbine flow meter 132 is used to adjust the opening of the first throttle valve 1311, so that about 5% of the two-phase fluid enters the second separator 133. This part of the fluid is the split fluid. After being separated by the second separator 133, the gas enters the gas flow meter 134 located at the upper end of the second separator 133 for measurement, and the liquid flows into the liquid flow meter 135 located at the lower end of the separator for measurement. The obtained data is transmitted to the data processing device 104 through a signal line. The data processing device 104 can determine the final two-phase parameter measurement result based on the received detection result.

[0053] Figure 3A flowchart illustrating a method for measuring gas-liquid two-phase parameters of wellhead drilling fluid according to an embodiment of this specification is provided. While this specification provides method operation steps or apparatus structures as shown in the following embodiments or figures, more or fewer operation steps or module units may be included in the method or apparatus based on conventional or non-inventive effort. In steps or structures where there is no logically necessary causal relationship, the execution order of these steps or the module structure of the apparatus is not limited to the execution order or module structure described in the embodiments and figures of this specification. When the method or module structure is applied in actual devices or end products, it can be executed sequentially or in parallel (e.g., in a parallel processor or multi-threaded processing environment, or even a distributed processing environment) according to the method or module structure shown in the embodiments or figures.

[0054] Specifically, such as Figure 3 As shown in the figure, the wellhead drilling fluid gas-liquid two-phase parameter measurement method provided in one embodiment of this specification may include the following steps.

[0055] Step S301: Obtain the first fluid parameters, second two-phase parameters, and third two-phase parameters of the gas-liquid two-phase fluid in the pipeline under test.

[0056] Step S302: Based on the first fluid parameter, the second two-phase parameter, and the third two-phase parameter, determine the measurement result of the two-phase parameter of the pipeline under test.

[0057] The method in this embodiment can be based on the wellhead drilling fluid gas-liquid two-phase parameter measurement system described in any of the above embodiments. Specifically, the method in this embodiment can be applied to the data processing device in the above system.

[0058] In some embodiments of this specification, determining the two-phase parameter measurement result of the pipeline under test based on the first fluid parameter, the second two-phase parameter, and the third two-phase parameter may include: converting the third two-phase parameter using the first fluid parameter to obtain the converted third two-phase parameter; calibrating the converted third two-phase parameter based on the second two-phase parameter to obtain the calibrated two-phase parameter; and fitting the calibrated two-phase parameter to the changing trend of the converted third two-phase parameter to obtain the two-phase parameter measurement result of the pipeline under test.

[0059] In some embodiments of this specification, the wellhead drilling fluid gas-liquid two-phase parameter measurement method may further include: controlling the opening and closing of the first ball valve and the second ball valve to perform timed or non-timed sampling of the gas-liquid two-phase fluid.

[0060] In some embodiments of this specification, the wellhead drilling fluid gas-liquid two-phase parameter measurement method may further include: controlling the opening degree of the first throttle valve based on the flow parameters detected by the turbine flow meter and a preset flow split percentage.

[0061] The various embodiments in this specification are described in a progressive manner. Similar or identical parts between embodiments can be referred to interchangeably. Each embodiment focuses on describing the differences from other embodiments. For details, please refer to the foregoing descriptions of the relevant processing embodiments; they will not be repeated here.

[0062] The foregoing has described specific embodiments of this specification. Other embodiments are within the scope of the appended claims. In some cases, the actions or steps recited in the claims may be performed in a different order than that shown in the embodiments and may still achieve the desired result. Furthermore, the processes depicted in the drawings do not necessarily require the specific or sequential order shown to achieve the desired result. In some embodiments, multitasking and parallel processing are possible or may be advantageous.

[0063] Based on the same inventive concept, this specification also provides a wellhead drilling fluid gas-liquid two-phase parameter measuring device, which can be applied to the wellhead drilling fluid gas-liquid two-phase parameter measuring system described in any of the above embodiments, as shown in the following embodiments. Since the principle of the wellhead drilling fluid gas-liquid two-phase parameter measuring device is similar to that of the wellhead drilling fluid gas-liquid two-phase parameter measuring method, the implementation of the wellhead drilling fluid gas-liquid two-phase parameter measuring device can refer to the implementation of the wellhead drilling fluid gas-liquid two-phase parameter measuring method, and repeated details will not be elaborated further. As used below, the terms "unit" or "module" can refer to a combination of software and / or hardware that performs a predetermined function. Although the device described in the following embodiments is preferably implemented in software, hardware implementation, or a combination of software and hardware, is also possible and contemplated. Figure 4 This is a structural block diagram of a wellhead drilling fluid gas-liquid two-phase parameter measuring device according to an embodiment of this specification, such as... Figure 4 As shown, it includes: an acquisition module 401 and a determination module 402. The structure is described below.

[0064] The acquisition module 401 is used to acquire the first fluid parameters, the second two-phase parameters, and the third two-phase parameters of the gas-liquid two-phase fluid in the pipeline under test.

[0065] The determination module 402 is used to determine the measurement results of the two-phase parameters of the pipeline under test based on the first fluid parameters, the second two-phase parameters, and the third two-phase parameters.

[0066] As can be seen from the above description, the embodiments of this specification achieve the following technical effects: by using a real-time separation and detection device, the fluctuations of the gas-liquid two-phase flow can be detected in real time; by using a sampling and detection device, the parameters of the gas-liquid two-phase fluid can be accurately measured; by comparing and verifying the measurement results obtained by the two methods, the real-time performance and accuracy can be complemented, thus having the characteristics of real-time measurement and accurate parameters, which can effectively improve the accuracy and efficiency of gas-liquid two-phase parameter measurement.

[0067] This specification also provides a computer device, which can be found in the following description. Figure 5 The diagram shown illustrates the computer device structure for the wellhead drilling fluid gas-liquid two-phase parameter measurement method provided in the embodiments of this specification. Specifically, the computer device may include an input device 51, a processor 52, and a memory 53. The memory 53 stores processor-executable instructions. When the processor 52 executes the instructions, it implements the steps of the wellhead drilling fluid gas-liquid two-phase parameter measurement method described in any of the above embodiments.

[0068] In this embodiment, the input device can specifically be one of the main devices for information exchange between the user and the computer system. The input device may include a keyboard, mouse, camera, scanner, light pen, handwriting input tablet, voice input device, etc.; the input device is used to input raw data and programs for processing these data into the computer. The input device can also receive data transmitted from other modules, units, and devices. The processor can be implemented in any suitable manner. For example, the processor can take the form of a microprocessor or processor and a computer-readable medium storing computer-readable program code (e.g., software or firmware) executable by the (micro)processor, logic gates, switches, application-specific integrated circuits (ASICs), programmable logic controllers, and embedded microcontrollers, etc. The memory can specifically be a memory device used to store information in modern information technology. The memory can include multiple layers; in digital systems, anything that can store binary data can be considered memory; in integrated circuits, a circuit without physical form but with storage function is also called memory, such as RAM, FIFO, etc.; in a system, a storage device with physical form is also called memory, such as a memory stick, TF card, etc.

[0069] In this embodiment, the specific functions and effects implemented by the computer device can be explained in comparison with other embodiments, and will not be repeated here.

[0070] This specification also provides a computer storage medium for a wellhead drilling fluid gas-liquid two-phase parameter measurement method, wherein the computer storage medium stores computer program instructions, which, when executed, implement the steps of the wellhead drilling fluid gas-liquid two-phase parameter measurement method described in any of the above embodiments.

[0071] In this embodiment, the storage medium includes, but is not limited to, random access memory (RAM), read-only memory (ROM), cache, hard disk drive (HDD), or memory card. The memory can be used to store computer program instructions. The network communication unit can be an interface configured according to standards specified in the communication protocol for network connection communication.

[0072] In this embodiment, the specific functions and effects implemented by the program instructions stored in the computer storage medium can be explained by comparison with other embodiments, and will not be repeated here.

[0073] Obviously, those skilled in the art will understand that the modules or steps of the embodiments described above can be implemented using general-purpose computing devices. They can be centralized on a single computing device or distributed across a network of multiple computing devices. Optionally, they can be implemented using computer-executable program code, thereby storing them in a storage device for execution by a computing device. In some cases, the steps shown or described can be performed in a different order than those presented herein, or they can be fabricated as separate integrated circuit modules, or multiple modules or steps can be fabricated as a single integrated circuit module. Thus, the embodiments of this specification are not limited to any particular combination of hardware and software.

[0074] It should be understood that the above description is for illustrative purposes and not for limitation. Many embodiments and applications beyond the provided examples will be apparent to those skilled in the art upon reading the above description. Therefore, the scope of this specification should not be determined by reference to the above description, but rather by reference to the foregoing claims and the full scope of their equivalents.

[0075] The above description is merely a preferred embodiment of this specification and is not intended to limit this specification. Various modifications and variations can be made to the embodiments described herein by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this specification should be included within the scope of protection of this specification.

Claims

1. A wellhead drilling fluid gas-liquid two-phase parameter measurement system, characterized in that, include: An inlet detection device is installed at the inlet of the gas-liquid two-phase fluid in the pipeline under test. It is used to perform non-contact measurement of the gas-liquid two-phase fluid at the inlet to obtain the first fluid parameters of the gas-liquid two-phase fluid. A sampling and testing device is installed in the middle section of the pipeline under test. When a gas-liquid two-phase fluid is introduced into the sampling pipe of the sampling and testing device, the sampling and testing device samples the gas-liquid two-phase fluid to obtain a gas-liquid two-phase fluid sample, and tests the gas-liquid two-phase fluid sample to obtain the second two-phase parameters of the gas-liquid two-phase fluid. The second two-phase parameters include gas phase fluid parameters and liquid phase fluid parameters. A real-time separation detection device is installed at the rear end of the pipeline under test. It is used to split the gas-liquid two-phase fluid flowing through the pipeline under test and to measure the split gas-liquid two-phase fluid to obtain the third two-phase parameters of the gas-liquid two-phase fluid. The third two-phase parameters include gas phase fluid parameters and liquid phase fluid parameters. The real-time separation and detection device includes: a first throttle valve, a turbine flow meter, a second separator, a gas flow meter, and a liquid flow meter; the first throttle valve is located at the rear end of the pipeline under test and is used to split the gas-liquid two-phase fluid flowing through the pipeline under test; the turbine flow meter is used to detect the flow parameters of the split gas-liquid two-phase fluid; the second separator is used to separate the split gas-liquid two-phase fluid; the gas flow meter is connected to the gas outlet of the second separator and is used to measure the flow parameters of the separated gas; the liquid flow meter is connected to the liquid outlet of the second separator and is used to measure the flow parameters of the separated liquid. A data processing device, communicatively connected to the inlet detection device, the sampling detection device, and the real-time separation detection device, is used to determine the two-phase parameter measurement results of the tested pipeline based on the first fluid parameter, the second two-phase parameter, and the third two-phase parameter. Specifically, the data processing device is used to convert the third two-phase parameter using the first fluid parameter to obtain the converted third two-phase parameter; it is also used to calibrate the converted third two-phase parameter based on the second two-phase parameter to obtain the calibrated two-phase parameter; and it is also used to fit the calibrated two-phase parameter to the changing trend of the converted third two-phase parameter to obtain the two-phase parameter measurement results of the tested pipeline.

2. The wellhead drilling fluid gas-liquid two-phase parameter measurement system according to claim 1, characterized in that, The inlet detection device includes an ultrasonic flow meter and a thermometer; The ultrasonic flow meter is used for non-contact flow measurement of gas-liquid two-phase fluids to obtain the flow parameters of the gas-liquid two-phase fluids. The thermometer is used for non-contact temperature measurement of a gas-liquid two-phase fluid to obtain its temperature parameters.

3. The wellhead drilling fluid gas-liquid two-phase parameter measurement system according to claim 1, characterized in that, The sampling and testing device includes: a three-way connector, a first ball valve, a second ball valve, a first switch, a first separator, a gas mass measuring instrument, and a liquid mass measuring instrument; wherein, The tee connector is located in the middle section of the pipeline being tested; The first ball valve is disposed between the three-way connector and the first separator, and the first switch is disposed between the first ball valve and the second ball valve; the first ball valve and the second ball valve are used to open simultaneously when the gas-liquid two-phase fluid is introduced into the sampling pipe, and are also used to close simultaneously when the fluid state introduced into the sampling pipe is stable, so as to obtain a gas-liquid two-phase fluid sample; The first switch is used to open when the first ball valve and the second ball valve are closed, so that the gas-liquid two-phase fluid sample in the sampling pipeline flows into the first separator; The first separator is used to measure the mass of the incoming gas-liquid two-phase fluid sample to obtain the mass parameters of the gas-liquid two-phase fluid sample, and is also used to separate the gas-liquid two-phase fluid sample to obtain the separated gas sample and liquid sample. The gas mass measuring instrument is connected to the gas outlet of the first separator and is used to measure the mass parameters of the separated gas sample. The liquid mass measuring instrument is connected to the liquid outlet of the first separator and is used to measure the mass parameters of the separated liquid sample.

4. The wellhead drilling fluid gas-liquid two-phase parameter measurement system according to claim 3, characterized in that, The first ball valve and the second ball valve are communicatively connected to the data processing device; the data processing device is used to control the opening and closing of the first ball valve and the second ball valve to perform timed or non-timed sampling of the gas-liquid two-phase fluid.

5. The wellhead drilling fluid gas-liquid two-phase parameter measurement system according to claim 1, characterized in that, The first throttle valve and the turbine flow meter are communicatively connected to the data processing device; The data processing device is used to control the opening degree of the first throttle valve based on the flow parameters detected by the turbine flow meter and the preset flow split percentage.

6. The wellhead drilling fluid gas-liquid two-phase parameter measurement system according to claim 5, characterized in that, The outlet of the real-time separation detection device is connected to the pipeline under test, so that the gas measured by the gas flow meter and the liquid measured by the liquid flow meter flow into the pipeline under test.

7. A method for measuring gas-liquid two-phase parameters of drilling fluid at the wellhead, characterized in that, Based on the wellhead drilling fluid gas-liquid two-phase parameter measurement system according to any one of claims 1 to 6, the method includes: Obtain the first fluid parameters, second two-phase parameters, and third two-phase parameters of the gas-liquid two-phase fluid in the pipeline under test; Based on the first fluid parameter, the second two-phase parameter, and the third two-phase parameter, the measurement results of the two-phase parameter of the pipeline under test are determined.

8. The method for measuring the gas-liquid two-phase parameters of drilling fluid at the wellhead according to claim 7, characterized in that, Based on the first fluid parameter, the second two-phase parameter, and the third two-phase parameter, the measurement results of the two-phase parameter of the tested pipeline are determined, including: The third two-phase parameters are converted using the first fluid parameters to obtain the converted third two-phase parameters. The converted third two-phase parameters are calibrated based on the second two-phase parameters to obtain the calibrated two-phase parameters. By combining the changing trend of the converted third two-phase parameter with the calibrated two-phase parameter, the measurement results of the two-phase parameter of the pipeline under test are obtained.

Images