Oil-Swellable Packer Activation via Oleaginous Fluid Density
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Solution Overview
Problem
Conventional wellbore fluids used for packer elements and swellable polymers lack sufficient density and stability, particularly in high-pressure formations, and often face issues with solid settlement due to the use of solid weighting agents, which can settle over time without circulation.
Innovation Solution
The introduction of an oil-containing wellbore fluid with an oleaginous continuous phase and an organophilic coated weighting agent, which is free from unassociated surfactants and emulsifiers, to activate oil-swellable packer systems, providing a higher density and minimizing settlement risks.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Quantity of substance
If solid weighting agents are used in packer fluids, then density can be increased, but solid settlement occurs over time without circulation
Solution Approach 1:
The patent changes the physical state of the weighting agent from solid to liquid by using an oleaginous fluid as the continuous phase. This allows the fluid to achieve high density (up to 21-22 ppg) while eliminating solid settlement issues, as the liquid weighting agent remains suspended in the oleaginous continuous phase without circulating.
Solution Approach 2:
The patent employs a liquid weighting agent suspended in an oleaginous continuous phase, creating a hydraulic system where the liquid weighting agent remains stably suspended through the continuous phase matrix. This hydraulic approach prevents gravitational settling that plagues solid weighting agents in conventional packer fluids.
2Ease of operation
If conventional wellbore fluids are used for packer elements, then ease of operation is maintained, but sufficient density and stability are not achieved in high-pressure formations
Solution Approach 1:
The patent creates a composite fluid system combining an oleaginous continuous phase with a liquid weighting agent. This composite formulation achieves the necessary density (up to 21-22 ppg) and stability for high-pressure formations while maintaining ease of operation, as the fluid remains pumpable and free-flowing despite the high density.
Solution Approach 2:
The patent modifies the physical parameters of the wellbore fluid by using an oleaginous continuous phase instead of water-based or conventional fluids. This parameter change enables the fluid to achieve high density while maintaining operational characteristics such as pumpability and flow, thus resolving the contradiction between ease of operation and stability in high-pressure environments.
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 solution achieves a higher density wellbore fluid that effectively activates oil-swellable packer systems, maintaining stability and preventing solid settlement, thereby enhancing wellbore integrity and sealing capabilities.
Implementation Method 1
contacting the oil-containing wellbore fluid with an oil-swellable element in the wellbore; and allowing swelling of the oil-swellable element
Implementation Method 2
The column of fluid in the hole exerts a hydrostatic pressure proportional to the depth of the hole and the density of the fluid. High-pressure formations may utilize a fluid with a density as high as about 10 pounds per gallon (ppg) and in some instances may be as high as 21 or 22 ppg.
Data Source
AI summary
A method for completing a wellbore may include introducing an oil-containing wellbore fluid into a wellbore having water-based filtercake on walls thereof, contacting the oil-containing wellbore fluid with an oil-swellable element in the wellbore; and allowing swelling of the oil-swellable element, where the oil-containing wellbore fluid is substantially free of unassociated surfactants, emulsifiers, or dispersants and may include an oleaginous fluid and a weighting agent.