Distributed Acoustic Sensing for Selective Wellbore Stimulation
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Solution Overview
Problem
In shale reservoirs, low reservoir matrix permeability necessitates hydraulic fracturing for economic hydrocarbon production, but production logging to evaluate inflow performance is risky and costly, often resulting in tool sticking and unexpected production losses due to wellbore obstructions.
Innovation Solution
Deployment of a distributed sensor array equipped coiled tubing with a hydrajet tool apparatus for selective stimulation, allowing precise identification and targeted fracturing of underperforming reservoir zones using fiber optic sensors to measure pressure, temperature, and fluid flow, enabling continuous coiled tubing operations.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If wireline tools with down hole tractor device are used for production logging, then inflow performance evaluation is improved, but tool sticking and production losses increase due to wellbore obstructions
Solution Approach 1:
The patent replaces the mechanical wireline tool system with a distributed acoustic sensing (DAS) system using optical fibers. The DAS system uses acoustic wave detection instead of mechanical tools to evaluate inflow performance, eliminating the risk of tool sticking while maintaining measurement capability. The optical fiber acts as a distributed sensor along the wellbore, detecting acoustic signatures from flowing hydrocarbons without physical contact with the formation.
2Loss of information
If production logging is performed to evaluate inflow performance, then underperforming zones can be identified, but unexpected production losses occur due to tool sticking
Solution Approach 1:
The patent uses distributed acoustic sensing (DAS) technology to identify underperforming zones without deploying mechanical logging tools. The optical fiber sensors detect acoustic emissions from flowing hydrocarbons, allowing identification of productive and non-productive zones along the wellbore. This eliminates the risk of tool sticking while providing comprehensive zone evaluation data for targeted stimulation planning.
3Productivity
If hydraulic fracturing is performed without selective stimulation, then reservoir stimulation is achieved, but underperforming zones cannot be specifically targeted
Solution Approach 1:
The patent performs preliminary identification of underperforming zones using distributed acoustic sensing (DAS) before conducting hydraulic fracturing. The DAS system maps acoustic signatures along the wellbore to identify specific zones with low production. This preliminary information allows planners to target only the identified underperforming zones with selective fracturing, improving both productivity and targeting precision compared to non-selective stimulation.
Solution Approach 2:
The patent applies local quality by using distributed acoustic sensing to identify specific local zones along the wellbore that require stimulation. Instead of treating the entire wellbore uniformly, the system detects acoustic variations at different locations and targets only the underperforming segments with hydraulic fracturing, achieving precise local intervention rather than blanket treatment.
4Ease of repair
If workover operations are performed to remove stuck logging tools, then tool recovery is achieved, but unexpected production losses and increased costs occur
Solution Approach 1:
The patent replaces mechanical logging tools with a distributed acoustic sensing system based on optical fibers. This substitution eliminates the need for workover operations to remove stuck tools, as the optical fiber system does not suffer from the same mechanical sticking issues. The DAS system provides continuous monitoring capability without requiring physical tool deployment and retrieval, thereby preventing production losses associated with workover operations.
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
This method allows for precise identification and selective stimulation of underperforming zones, reducing the risk of tool sticking and production losses by enabling continuous coiled tubing operations, thereby optimizing hydrocarbon production and minimizing workover operations.
Implementation Method 1
equipped coiled tubing with a hydrajet tool apparatus for selective stimulation, allowing precise identification and targeted fracturing of underperforming reservoir zones using fiber optic sensors to measure pressure, temperature, and fluid flow
Implementation Method 2
selective fracturing of selected areas of a formation
Data Source
AI summary
A selective stimulation system includes coiled tubing in which a distributed sensor array is disposed. The distributed sensor array is to measure hydrocarbon production parameters along the distributed sensor array in a wellbore of a formation. A selective fracturing apparatus is coupled to the coiled tubing. The selective fracturing apparatus is to fracture selected areas of the wellbore. A controller is coupled to the distributed sensor array and controls operation of the selective fracturing apparatus based on the measured hydrocarbon production parameters.