Gemini and Zwitterionic Surfactant Diversion Agents
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Solution Overview
Problem
Conventional well stimulation methods, such as matrix acidizing, are ineffective in creating conductive pathways for hydrocarbon production due to low viscosity acids that primarily penetrate high permeability zones, leaving low permeability zones untreated in heterogeneous reservoirs.
Innovation Solution
The use of wellbore fluids containing a gemini surfactant, a zwitterionic surfactant, and an activator, which increase in viscosity under downhole temperature conditions, diverting fluid flow from high to low permeability zones and enhancing hydrocarbon recovery by creating pathways for production.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Ease of operation
If low viscosity acid is used for matrix stimulation, then the acid can be easily injected into the formation, but the acid has limited penetration depth and only reacts at the face of the rock
Solution Approach 1:
The patent uses temperature-responsive viscosity changing to resolve the contradiction between injectability and penetration depth. The wellbore fluid has low viscosity at injection temperature for easy injection, then increases viscosity at formation temperature to enhance penetration depth and create conductive pathways.
Solution Approach 2:
The patent applies dynamic viscosity adjustment based on temperature conditions. The fluid transitions from a low-viscosity state during injection to a high-viscosity state in the formation, allowing it to adapt to different operational requirements at different stages of the process.
2Ease of operation
If low viscosity acid is used for matrix stimulation, then the acid can be easily injected into the formation, but conductive pathways for hydrocarbon production are not created
Solution Approach 1:
The patent changes the viscosity parameter of the wellbore fluid based on temperature to simultaneously achieve easy injection and effective pathway creation. The low viscosity at injection temperature ensures ease of operation, while the high viscosity at formation temperature enables deep penetration and conductive pathway formation for hydrocarbon production.
Solution Approach 2:
The dynamic viscosity adjustment allows the fluid to perform different functions at different stages: easy injection during transport, then deep penetration and pathway creation in the formation, thereby improving both injectability and hydrocarbon production capability.
3Ease of operation
If low viscosity acid is used for matrix stimulation, then the acid can be easily injected into the formation, but heterogeneous permeabilities result in the acid primarily penetrating the high permeable zones and leaving low permeability zones untreated
Solution Approach 1:
The patent uses temperature-induced viscosity changes to improve adaptability to heterogeneous permeability zones. The low viscosity at injection temperature allows easy injection throughout the formation, while the high viscosity at formation temperature slows flow in high permeability zones and redirects acid into low permeability zones, achieving uniform treatment coverage.
Solution Approach 2:
The dynamic viscosity adjustment enables the fluid to adapt to varying permeability conditions. Initially, the low-viscosity state allows uniform distribution across different zones, then the high-viscosity state creates flow diversion that ensures adequate treatment of both high and low permeability zones.
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 increased viscosity of the wellbore fluids allows for improved sweep efficiency and uniform reaction with the reservoir, creating deeper pathways and enhancing permeability, thereby increasing hydrocarbon recovery from previously untreated low permeability zones.
Implementation Method 1
The surfactants may be viscoelastic. Methods may involve injecting the wellbore fluids into a formation, exposing the fluid to an increased temperature and resulting in the wellbore fluid having an increased viscosity.
Implementation Method 2
exposing the fluid to an increased temperature and resulting in the wellbore fluid having an increased viscosity
Implementation Method 3
wellbore fluids that include a gemini surfactant, a zwitterionic surfactant, an activator, and an aqueous base fluid
Implementation Method 4
The surfactants may be viscoelastic
Data Source
AI summary
A wellbore fluid may include a gemini surfactant, a zwitterionic surfactant; an activator, and an aqueous base fluid. The gemini surfactant may have a structure represented by formula (I):where R1 is a C1-C6 hydrocarbon group or a monovalent cation, R2 is a C1-C10 hydrocarbon group, m is an integer ranging from 1 to 4, n is an integer ranging from 8 to 12, and X is a monovalent anion.