Multiphase Flowmeter with Acoustic Sensors and Inline Conditioners
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Solution Overview
Problem
Conventional multiphase flow meters are hazardous, expensive, and fail to provide real-time, accurate measurements of oil, water, and gas production in hydrocarbon fields, especially when dealing with gas phases, limiting efficient production management and reservoir engineering.
Innovation Solution
A multiphase flow meter system comprising inline flow conditioners to reduce slip velocity, non-radioactive sensors for gas void fraction and water-cut measurements, and a processor to compute flow rates of gas and liquid phases, enabling real-time, accurate data collection without the use of gamma-ray sensors.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If conventional gamma-ray sensors are used for multiphase flow measurement, then measurement capability is provided, but safety hazards and high costs occur
Solution Approach 1:
The patent replaces gamma-ray sensors with acoustic sensors that detect multiphase flow characteristics through sound waves. The acoustic sensor subsystem measures gas void fraction and water cut by analyzing acoustic signals transmitted through the fluid, eliminating radioactive materials while maintaining measurement capability. This substitution of detection mechanism resolves the safety hazard issue while preserving measurement precision.
2Measurement precision
If conventional multiphase flow meters are used, then flow measurement is provided, but real-time accuracy and gas phase handling capability are insufficient
Solution Approach 1:
The patent segments the measurement process into distinct functional components: a flow meter for total flow rate measurement, a gas void fraction sensor for gas phase characterization, and a water cut sensor for liquid phase composition. Each sensor targets specific flow parameters, and their combined data provides comprehensive real-time measurement of multiphase flow including gas phase, improving both accuracy and reliability through specialized measurement for each phase.
3Measurement precision
If inline flow conditioners are added to reduce slip velocity, then measurement accuracy is improved, but device complexity increases
Solution Approach 1:
The patent incorporates inline flow conditioners upstream of the sensors to pre-condition the multiphase flow by reducing slip velocity between gas and liquid phases. This preliminary action creates a more uniform flow distribution before measurement, improving sensor accuracy. The flow conditioners are integrated into the existing pipeline flow path, minimizing additional complexity while achieving the measurement improvement.
Applied Scientific Principles
This section explains which scientific principles are used to turn an abstract innovation direction into a practical engineering solution.
Function Achieved in This Case
The system provides safe, cost-effective, and accurate real-time measurements of multiphase flow properties, improving oil production management and reservoir engineering by identifying underperforming wells and optimizing recovery factors.
Implementation Method 1
a non-radioactive sensor subsystem for communicating data representing a gas void fraction of the multiphase fluid and a water-cut of the multiphase fluid
Implementation Method 2
a flow meter including one or more flow sensors for communicating data representing a total flow rate of the multiphase fluid
Data Source
AI summary
Embodiments include a multiphase flowmeter system (300). The multiphase flowmeter system (300) may include a first inline flow conditioner (310) for reducing a slip velocity between a liquid phase and a gas phase of a multiphase fluid, a flowmeter for measuring a flow rate of the multiphase fluid, a second inline flow conditioner (350) for separating the liquid phase and the gas phase of the multiphase fluid, a non-radioactive sensor system for measuring one or more of a gas void fraction of the multiphase fluid and a water-cut of the multiphase fluid, and a processor (480) for computing one or more flow rates of the multiphase fluid. Embodiments further include methods of measuring one or more flow rates of a multiphase fluid and other related methods, apparatuses, devices, and systems.