Multi-phase Flow Metering with Coriolis and Water Cut Probe
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Solution Overview
Problem
Conventional Coriolis flowmeters struggle to accurately measure three-phase oil/water/gas mixtures from oil and gas wells, as they require simplifying assumptions and cannot account for variations in fluid composition, leading to inaccurate net oil production calculations.
Innovation Solution
A multi-phase flow metering system incorporating a Coriolis flowmeter and a water cut probe, which measures mass flow, density, and water cut, along with a self-validating sensor and dynamic uncertainty analysis, to provide accurate and real-time measurements of oil, water, and gas flow rates without the need for separation, facilitating true three-phase metering.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If a conventional Coriolis flowmeter is used to measure three-phase oil/water/gas mixtures, then mass flow and density can be measured, but accurate resolution of three-phase composition cannot be achieved without simplifying assumptions
Solution Approach 1:
The patent combines a Coriolis flowmeter with a water cut probe into an integrated measurement system. The Coriolis flowmeter provides mass flow and density measurements while the water cut probe measures the water content in the liquid phase. By merging these two measurement devices and combining their data through a measurement model, the system achieves accurate three-phase composition resolution without requiring simplifying assumptions about fluid properties.
2Measurement precision
If a test separator is used to separate and measure oil and gas flow rates, then volumetric flow rates can be obtained, but the flow path differences cause measurements to not represent actual well production
Solution Approach 1:
The patent extracts the measurement function from the conventional test separator system and implements it directly in the flow line using a Coriolis flowmeter. This eliminates the need for separate test separators and complex flow path configurations. The Coriolis flowmeter measures mass flow and density directly in the production flow, providing representative measurements of actual well production without the distortions introduced by separator flow paths.
3Measurement precision
If multiple measurement systems are used to achieve accurate three-phase metering, then measurement accuracy improves, but system footprint and maintenance requirements increase
Solution Approach 1:
The patent merges multiple measurement functions into a single integrated system. The Coriolis flowmeter and water cut probe are combined into one compact measurement unit that provides all necessary measurements (mass flow, density, water cut) for accurate three-phase composition resolution. This integrated approach achieves the measurement accuracy of multiple separate systems while occupying minimal space and reducing maintenance requirements.
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
Enables precise and dynamic measurement of net oil flow rates, reducing maintenance and system footprint, while ensuring accurate flow rate capture within minutes, meeting industry standards for accuracy and uncertainty analysis.
Implementation Method 1
The physics of the device dictates that Coriolis forces act along the measurement section between sensors, resulting in a phase difference between the sinusoidal sensor signals. This phase difference is essentially proportional to the mass flow rate of the fluid passing through the measurement section.
Implementation Method 2
The frequency of oscillation of the flowtube of a Coriolis meter varies with the density of the process fluid in the flowtube. The frequency value can be extracted from the sensor signals (for example by calculating the time delay between consecutive zero crossings) so that the density of the fluid can be obtained.
Data Source
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AI summary
A net oil and gas well test system for a set of oil and gas wells includes at least two net oil and gas measurement systems and a plurality of valves that are in fluid communication with the individual wells in the set and independently configurable between a first state, in which the valve routes flow to a first net oil and gas measurement system, and a second state, in which the valve routes flow to a second net oil and gas measurement system. Each net oil and gas measurement system suitably has the capability to measure a multiphase flow including oil, gas, and water without separation. For example, each measurement system can include a multiphase Coriolis meter and a water cut meter. Each measurement system suitably includes the capability to provide dynamic uncertainty estimates related to measurement of the multiphase flow.