Invert Emulsion Wellbore Fluid Density Adjustment
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Solution Overview
Problem
The use of oil-based and synthetic-based wellbore fluids in drilling operations poses challenges due to their high value and environmental concerns associated with disposal, as well as difficulties in modifying their properties after initial formulation, such as increasing salinity or density, which is necessary for reuse.
Innovation Solution
A method involving the use of a mixing unit with high shear rates (10,000 to 100,000 s^-1) to add dry additives like salt, salt-tolerant clay, or synthetic polymers to the non-oleaginous phase of invert emulsion wellbore fluids, allowing for adjustment of properties like salinity and density, thereby modifying the fluid's properties for reuse.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Quantity of substance
If dry additives are added to invert emulsion wellbore fluid, then the density and salinity of the fluid can be increased, but the fluid properties become difficult to modify and may become unstable
Solution Approach 1:
The patent applies parameter changes by controlling the water activity of the internal aqueous phase within a specific range (0.70 to 0.95) to enable modification of fluid density through additive incorporation while maintaining emulsion stability. This parameter control allows the fluid properties to be adjusted without compromising the overall stability of the invert emulsion system.
Solution Approach 2:
The patent uses an intermediary approach by controlling water activity as a mediating parameter between additive concentration and emulsion stability. By adjusting water activity within the specified range, the system can incorporate density-increasing additives while the water activity acts as a buffer to prevent destabilization of the invert emulsion structure.
2Quantity of substance
If the concentration of non-oleaginous liquid in invert emulsion is increased, then the density of the wellbore fluid increases, but the lubrication properties deteriorate
Solution Approach 1:
The patent applies parameter changes by controlling the water activity of the internal phase rather than simply increasing non-oleaginous liquid concentration. This allows density adjustment through dissolved solids (salts) while maintaining the oleaginous continuous phase proportion, thereby preserving lubrication properties. The water activity parameter serves as a controlled variable to achieve density increase without compromising lubrication.
3Object-generated harmful factors
If oil-based wellbore fluids are used to provide excellent lubrication, then pipe sticking is prevented, but the cost increases and environmental concerns arise
Solution Approach 1:
The patent applies parameter changes by controlling water activity to enable the reuse and recycling of oil-based wellbore fluids. By adjusting water activity within the specified range, the fluid can be modified for different applications while maintaining its lubrication properties, thereby extending its service life and reducing disposal requirements and environmental impact.
Solution Approach 2:
The patent implements discarding and recovering principles by enabling the recycling of used oil-based wellbore fluids. The controlled water activity modification allows spent fluids to be rejuvenated and reused, reducing the need for continuous disposal and new fluid preparation, thereby addressing environmental concerns associated with oil-based fluid disposal.
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 efficient alteration of wellbore fluid properties, such as salinity and density, facilitating the reuse of wellbore fluids while maintaining their stability and environmental sustainability.
Implementation Method 1
delivering the invert emulsion wellbore fluid and the additive to one or more stages of the mixing unit having a shear rate ranging from about 10,000 s-1 to about 100,000 s-1
Data Source
AI summary
Embodiments disclosed herein relate to a method including feeding an invert emulsion wellbore fluid, or a previously used invert emulsion wellbore fluid, into a mixing unit; adding an additive to the mixing unit; delivering the invert emulsion wellbore fluid and the additive to one or more stages of the mixing unit, the mixing unit having a shear rate ranging from about 10,000 s-1 to about 100,000 s-1. The invert emulsion wellbore fluid includes a non-oleaginous fluid being the discontinuous internal aqueous phase of the wellbore fluid, and an oleaginous fluid being the continuous external phase of the wellbore fluid.