Initial Wellbore Fluid Distribution Inference for Coiled Tubing Cleanout
Find Innovative SolutionsGenerate Solutions
Solution Overview
Problem
Existing coiled tubing operations face challenges in accurately determining initial wellbore fluid distribution and reservoir pressure, which affects the design and execution of cleanout and descaling operations due to unknown parameters such as solid fill positions and debris size distribution, leading to uncertain under- or over-balanced conditions.
Innovation Solution
A method and system that utilize sensors to detect operating parameters during coiled tubing operations, infer initial wellbore fluid distribution, and determine reservoir pressure, enabling real-time automation and optimization of cleanout operations by predicting fluid circulation behavior and minimizing risks of solid influx.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If traditional coiled tubing operations are performed without inferring reservoir pressure, then operational simplicity is maintained, but accuracy of reservoir pressure determination and fluid distribution knowledge deteriorates
Solution Approach 1:
The patent replaces direct mechanical pressure measurement systems with an inference system that uses sensor data (temperature, pressure, flow rate) and computational algorithms to determine reservoir pressure and fluid distribution. This substitution achieves accurate measurements without requiring complex downhole pressure gauges or direct contact with reservoir fluids.
Solution Approach 2:
The patent introduces an intermediary inference system that acts as a mediator between available sensor data and the desired reservoir pressure information. This system uses detected operating parameters as intermediaries to calculate and determine reservoir pressure and fluid distribution indirectly, avoiding the need for direct measurement devices.
2Loss of information
If sensors and inference systems are implemented during coiled tubing operations, then reservoir pressure and fluid distribution are accurately determined, but device complexity and cost increase
Solution Approach 1:
The patent makes the coiled tubing system multi-functional by enabling it to perform both its primary cleanout function and secondary measurement/inference functions simultaneously. The same sensors and processing systems serve multiple purposes: monitoring operational parameters, inferring reservoir pressure, and determining fluid distribution, thereby reducing the need for separate dedicated measurement devices.
Solution Approach 2:
The patent enables the coiled tubing system to self-determine its operational environment by using its own sensors and processing capabilities to infer reservoir pressure and fluid distribution. The system serves itself by generating and processing its own data to understand the wellbore conditions without requiring external measurement equipment.
3Productivity
If real-time sensor data is collected and processed during coiled tubing operations, then operational optimization is achieved, but data processing requirements and computational demands increase
Solution Approach 1:
The patent applies partial action by selectively processing only the most critical sensor data and parameters needed for operational optimization. Rather than analyzing all possible data streams in real-time, the system focuses on key parameters (temperature, pressure, flow rate) that have the greatest impact on reservoir pressure inference and operational decisions, reducing computational overhead.
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 accurate determination of reservoir pressure and fluid distribution, allowing for optimized coiled tubing operations by ensuring safe and efficient removal of debris, reducing the risk of under- or over-balanced conditions, and improving operational efficiency.
Implementation Method 1
detecting data relating to one or more operating parameters of the coiled tubing operation via one or more sensors of the coiled tubing system during the coiled tubing operation
Implementation Method 2
determining an initial wellbore fluid distribution in the wellbore based at least in part on the detected data prior to pumping fluid into the wellbore from a surface location
Implementation Method 3
inferring a reservoir pressure of a hydrocarbon-bearing reservoir through which the wellbore extends based at least in part on the initial wellbore fluid distribution in the wellbore
Data Source
AI summary
Systems and methods presented herein facilitate coiled tubing operations, and generally relate to automatically improving performance of coiled tubing operations in substantially real time by inferring reservoir pressure based on initial coiled tubing run conditions. For example, a method includes performing a coiled tubing operation via a coiled tubing system at least partially disposed within a wellbore. The method also includes detecting data relating to operating parameters of the coiled tubing operation via sensors of the coiled tubing system during the coiled tubing operation. The method further includes determining an initial wellbore fluid distribution in the wellbore based on the detected data prior to pumping fluid into the wellbore from a surface location relative to the wellbore. In addition, the method includes inferring a reservoir pressure of a hydrocarbon-bearing reservoir through which the wellbore extends based on the initial wellbore fluid distribution in the wellbore.