Fluid Sensor Cable Assembly for Real-Time Multiphase Flow Measurement
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Solution Overview
Problem
Current multiphase measurement devices for wells are limited by long heating times and uneven heating, which reduces the resolution and accuracy of fluid flow rate measurements, and cannot provide real-time measurements during resource extraction, and are unable to measure individual flow rates of different fluids like oil, water, and gas.
Innovation Solution
A fluid sensor cable assembly with an elongated core body, conductive bodies for heating and signal transmission, and optical fibers with temperature-sensitive elements that measure heat flux, allowing for real-time distributed phase and flow velocity measurements in subterranean wells, enabling concurrent measurement of fluid phases and velocities during production.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Temperature
If heating is performed using elongated cables to measure fluid flow rates, then the well can be heated to enable measurement, but the heating time becomes significantly long and heating becomes uneven
Solution Approach 1:
The heating function is segmented into multiple independent heating zones along the cable assembly, allowing different sections to be heated simultaneously or independently, reducing total heating time and enabling targeted heating of specific well sections
Solution Approach 2:
The heating cables are designed with varying heating characteristics in different sections to match the specific thermal requirements of different well zones, enabling more uniform and efficient heating distribution throughout the wellbore
2Temperature
If heating is performed using elongated cables to measure fluid flow rates, then the well can be heated to enable measurement, but the heating becomes uneven
Solution Approach 1:
The heating system is divided into multiple independently controlled segments along the cable length, allowing precise control of temperature distribution to achieve uniform heating across different well sections
Solution Approach 2:
Each heating zone can be independently adjusted to provide the exact heating intensity needed for that specific location, compensating for variations in thermal conductivity and fluid flow conditions throughout the well
3Measurement precision
If multiphase measurement devices are used to measure fluid flow rates, then flow rate data can be obtained, but real-time measurements during resource extraction cannot be provided
Solution Approach 1:
The cable assembly is designed to perform multiple functions simultaneously - heating, flow measurement, and phase identification - allowing continuous operation during both production and non-production periods without requiring separate devices
Solution Approach 2:
The measurement system is designed to dynamically adapt to changing well conditions during production, providing real-time data that reflects actual flowing conditions rather than static measurements taken during shut-in periods
4Measurement precision
If multiphase measurement devices are used to measure fluid flow rates, then total flow rate can be measured, but individual flow rates of different fluids cannot be measured
Solution Approach 1:
The measurement system segments the total flow measurement into individual phase measurements by detecting characteristic signatures of different phases (oil, water, gas) at multiple locations along the cable, allowing reconstruction of individual phase flow rates
Solution Approach 2:
The cable assembly measures local thermal and electrical properties at multiple discrete points along its length, and by analyzing variations in these local measurements, the system can distinguish and quantify different fluid phases and their individual flow rates
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 real-time logging of fluid velocities and phases across multiple perforations and zones, optimizing reservoir production, improving fracture management, and increasing production rates, while validating seismic models and managing resources like water and gas.
Implementation Method 1
The one or more conductive bodies are configured to conduct a heating current along the length of the core body to heat the fluid sensor cable assembly
Implementation Method 2
The temperature sensitive elements are configured to measure heat flux out of the fluid sensor cable assembly at the different locations along the length of the core body subsequent to heating the fluid sensor cable assembly
Implementation Method 3
The one or more conductive bodies also are configured to conduct an interrogation signal along the length of the core body and to conduct reflections of the interrogation signal as distributed phase measurement signals
Data Source
AI summary
A fluid sensor cable assembly and method uses one or more conductive bodies extending along an elongated core body for conducting a heating current to heat the cable assembly. The one or more conductive bodies also are configured to conduct an interrogation signal and to conduct reflections of the interrogation signal. One or more optical fibers extend along the length of the core body and include temperature sensitive elements at different locations along the length of the core body. The temperature sensitive elements measure heat flux out of the cable assembly at the different locations subsequent to heating the cable assembly and communicate the heat flux to a computer acquisition system.