Optical Flow Imaging for Real-Time Particle Size Distribution
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Solution Overview
Problem
Current methods for measuring particle size distribution (PSD) of wellbore fluids in the oil and gas industry are time-consuming, often taking days or weeks, and lack real-time monitoring capabilities, which hinders optimal control of drilling operations and leads to losses due to changes in PSD during circulation.
Innovation Solution
Implementing on-site, real-time optical flow imaging techniques that use flow imaging devices to monitor and record the PSD of particulates in wellbore fluids, allowing for immediate adjustments to maintain optimal particle concentrations and prevent losses by tracking LCM and other particulates during circulation.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Loss of time
If traditional laboratory methods are used to measure particle size distribution, then measurement accuracy is maintained, but measurement time increases significantly (days or weeks)
Solution Approach 1:
The patent replaces traditional mechanical laboratory analysis methods with an optical measurement system using a camera and image processing algorithms. The flow imaging device captures images of particles in the drilling fluid and uses computer vision techniques to determine particle size distribution in real-time, eliminating the need for time-consuming laboratory procedures while maintaining measurement accuracy
Solution Approach 2:
The system creates optical copies (images) of the actual particles in the drilling fluid. By capturing visual representations of particles and analyzing these images computationally, the system determines PSD without physically handling or transporting samples to laboratories, thereby achieving rapid measurement while preserving measurement fidelity
2Productivity
If real-time optical flow imaging is implemented, then real-time PSD monitoring is achieved, but device complexity increases
Solution Approach 1:
The flow imaging device is designed to perform multiple functions: it captures images of particles, processes images to determine particle size, tracks PSD changes over time, and provides real-time data for drilling operation optimization. This multi-functionality consolidates what would otherwise require multiple separate systems into a single integrated device, managing complexity while enhancing productivity
Solution Approach 2:
The system incorporates automated image processing and analysis capabilities that operate without continuous human intervention. The computational algorithms automatically process captured images to extract PSD information, and the system self-manages the workflow from image capture to PSD determination, reducing operational complexity despite the advanced technology involved
3Reliability
If PSD monitoring is performed in real-time, then particle concentration control is improved, but measurement and processing costs increase
Solution Approach 1:
The system establishes a closed-loop feedback mechanism where real-time PSD measurements are continuously monitored and used to adjust drilling fluid composition and circulation parameters. This feedback control ensures reliable PSD management by automatically responding to changes in particle concentration, preventing losses, and optimizing drilling operations based on actual measured conditions
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 monitoring and adjustment of PSD, optimizing drilling operations by preventing losses and maintaining optimal particle concentrations, thereby improving control over subterranean reservoir conditions and reducing downtime.
Implementation Method 1
obtain an image of the particulates using the flow imaging device
Implementation Method 2
The capillary is backlit by a backlighting generator
Data Source
AI summary
An example well system including a drill string extending from a surface location into a wellbore and defining an annulus between the drill string and the wellbore, a fluid circuit extending through the drill string to a bottom of the wellbore and back to the surface location within the annulus, and further extending back to the drill string from the annulus, and one or more flow imaging devices in fluid communication with the fluid circuit to monitor the wellbore fluid and track a real-time particle size distribution (PSD) of one or more particulates suspended within the wellbore fluid.