Wellhead gas-liquid two-phase flow metering method and device

Abstract

The invention relates to a wellhead gas-liquid two-phase flow metering method and device. The device mainly comprises an ultrasonic transducer device integrating a bidirectional transceiving function, a filter amplifier, a threshold value comparison circuit, a liquid level sensor and a temperature sensor. The method includes that by adopting a novel mutual correlation algorithm, upstream-downstream time difference of an ultrasonic transducer can be calculated to detect and compensate originally measured time difference; a correlation algorithm based on discrete Fourier transformation is adopted for collected ultrasonic envelope signals to calculate a correlation value, a maximum correlation point is found out, time difference is calculated, time compensation is performed on a timer to acquire final time difference, and flow of gas phase and liquid phase in wellhead gas-liquid two-phase flow can be calculated according to liquid level, temperature and pipeline parameters measured by the sensors. The method is safe and harmless, free of causing disturbance to fluid, good in performance, low in cost, capable of effectively improving wellhead collecting and metering accuracy and high in reliability and stability.

Description

technical field [0001] The invention relates to a flow measurement method and device, in particular to a wellhead gas-liquid two-phase flow measurement method and device. Background technique [0002] At present, wellhead crude oil collection technology is developing rapidly, and various new, automated, and intelligent oil production equipment emerge in endlessly. However, in terms of wellhead crude oil measurement, it is faced with large errors, inaccurate measurement, untimely measurement, many human factors, and maintenance cycle. In traditional metering methods, hardware methods such as traditional metering room separators for measuring oil and non-separated multiphase flowmeters are greatly affected by human factors, and cause disturbance and instability to the fluid; software methods such as electric pump well software Oil measurement, oil measurement by differential pressure method, etc., are accompanied by discontinuity in the oil recovery process, and the gas-liquid...

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Problems solved by technology

[0002] At present, wellhead crude oil collection technology is developing rapidly, and various new, automated, and intelligent oil production equipment emerge in endlessly. However, in the aspect of wellhead crude oil measurement, it is faced with large errors, inaccurate measurement, untimely measurement, many human factors, and maintenance cycle. In traditional metering methods, hardware methods such as traditional metering room separators for measuring oil and non-separated multiphase flowmeters are greatly affected by human factors, and cause disturbance and instability to the fluid; software methods such as electric pump well software Oil measurement, oil measurement by differential pressure method, etc., are accompanied by discontinuity in the oil recovery process, and the gas-liquid two-phase mixed liquid is collected, so the gas volume cannot be measured; the error between the two can reach 10% - 20% or more

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