Palm Kernel Shell Particulate Fluid Loss Control
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Solution Overview
Problem
Wellbore servicing fluids face challenges in controlling fluid losses and preventing undesired production of water and gas from subterranean formations, leading to issues like sand production, scale, and corrosion, as well as difficulties in maintaining effective circulation and cement placement due to lost circulation zones.
Innovation Solution
A wellbore servicing fluid comprising a base fluid and particulate palm kernel shells, which are characterized by specific particle size distributions and amounts, is used to form a filter cake or plug permeable zones, reducing fluid loss and preventing influx of water and gas into the wellbore.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If wellbore servicing fluid is circulated in the wellbore, then drilling and servicing operations can be performed, but fluid is lost to the subterranean formation through lost circulation zones
Solution Approach 1:
The fluid system is segmented into multiple phases: free-flowing particulate material that can be pumped through the wellbore, and gelated material that forms the actual plug in the lost circulation zone. This segmentation allows the fluid to serve dual purposes - circulation during drilling and plugging when fluid loss occurs
Solution Approach 2:
The particulate material undergoes a parameter change from free-flowing state during circulation to gelated state when it contacts formation water or brine in the lost circulation zone. This parameter change (viscosity increase) enables the material to form an effective plug that stops fluid loss
2Reliability
If shut-off fluid is introduced into permeable zones, then water and gas production are prevented, but fluid loss to formation occurs
Solution Approach 1:
The particulate material automatically gelates upon contact with formation water or brine in the permeable zone, creating a self-forming plug that requires no additional chemicals or complex activation systems. The formation fluids themselves trigger the gelation process that seals the zone
3Stress or pressure
If fluid circulation is maintained in lost circulation zones, then wellbore pressure is sustained, but fluid continuously enters the formation
Solution Approach 1:
The particulate material acts as an intermediary substance that is pumped with the wellbore servicing fluid but remains suspended and does not immediately filter out. When it reaches the lost circulation zone, it gelates to form a plug that mediates between the wellbore pressure and the formation, allowing pressure maintenance while stopping fluid loss
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
The fluid effectively minimizes fluid loss and maintains wellbore pressure, allowing for continued drilling and effective cement placement by forming a bridging agent within the filter cake that withstands hydrostatic pressure and reduces permeable zone flow.
Implementation Method 1
forming a bridging agent within the filter cake that withstands hydrostatic pressure and reduces permeable zone flow
Implementation Method 2
zones having naturally-occurring fractures or induced fracture, weak zones having fracture gradients exceeded by the hydrostatic pressure of the wellbore servicing fluid
Data Source
AI summary
A method of servicing a wellbore penetrating a subterranean formation, the method including placing a wellbore servicing fluid into the wellbore proximate a permeable zone. The wellbore servicing fluid comprises a base fluid and from about 3 wt. % to about 25 wt. % by total weight of the wellbore servicing fluid of a particulate material. The particulate material comprises palm kernel shells.