Formation Fluid Boundary Detection Using Injectable Fluid Gradients
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Solution Overview
Problem
Current methods for determining the boundary between different formation fluids in subterranean formations during drilling operations often require penetrating the boundary, leading to contamination and inefficiencies in hydrocarbon extraction, as they lack the ability to accurately assess the boundary from one side without direct drilling through it.
Innovation Solution
A method and system that utilize a formation tester to create a hydraulic seal within a borehole, inject a compatible fluid to measure fluid gradients, and calculate the boundary between different formation fluids, allowing for the determination of the boundary without direct penetration, using data from probes and computational analysis.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If drilling operations directly penetrate the formation fluid boundary to determine its location, then the boundary position can be identified, but hydrocarbon contamination occurs and extraction efficiency decreases
Solution Approach 1:
The patent introduces an injectable fluid as an intermediary substance that mixes with formation fluids to create measurable concentration gradients. This intermediary approach allows boundary detection through fluid sampling and analysis without direct drilling penetration, thereby identifying the boundary location while preventing hydrocarbon contamination and maintaining extraction efficiency.
2Productivity
If drilling operations continue without accurate boundary determination, then drilling speed is maintained, but formation fluid mixing increases and requires additional water removal
Solution Approach 1:
The patent performs preliminary boundary detection by injecting fluids and sampling formation fluids before continuing drilling operations. This preliminary action provides advance knowledge of the boundary location, allowing drilling operations to be adjusted subsequently to avoid exacerbating fluid mixing, thereby maintaining both drilling speed and minimizing hydrocarbon-water mixing.
3Measurement precision
If formation tester injects miscible fluid into the subterranean formation to measure fluid gradients, then boundary determination accuracy improves, but additional equipment and operational complexity are required
Solution Approach 1:
The formation tester is designed with multi-functionality, serving both as a drilling tool and a fluid injection/sampling system. By integrating boundary detection capabilities into the existing formation tester equipment, the patent achieves accurate boundary determination without requiring entirely separate complex equipment, thereby improving measurement precision while managing device complexity.
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 approach enables precise determination of the formation fluid boundary, improving drilling efficiency, reducing contamination, and enhancing the accuracy of reservoir reserve estimation and well site operation planning.
Implementation Method 1
making a hydraulic seal of the formation tester with a fluid bearing formation
Implementation Method 2
injecting into the subterranean formation an injectable fluid miscible with the immobile phase fluid from the subterranean formation
Implementation Method 3
measuring at least one fluid gradient utilizing at least one fluid pressure of an immobile phase fluid
Data Source
AI summary
The disclosure presents processes to determine a first formation fluid-second formation fluid boundary from one side of the boundary utilizing a formation tester tool. For example, the formation tester can be utilized in a borehole to determine an engagement point with a subterranean formation and determine one or more, or a combination of, injectable fluids to inject into the subterranean formation. Sensors coupled to the formation tester can measure the rebound pressure of the injected fluids. In some aspects, the fluid density of the collected fluid can be measured. The measured pressure changes and other collected data, can be utilized to determine a first formation fluid-second formation fluid boundary parameter. Other characteristic parameters can also be determined such as wettability parameters, porosity parameters, and capillary effects parameters. The formation tester can collect a core sample and an analyzation of the core sample can be utilized to determine the characteristic parameters.