Surfactant Foam Formulation for Harsh-Reservoir Mobility Control
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Solution Overview
Problem
Conventional foam formulations and generation methods fail to produce stable and effective foams for enhanced oil recovery due to reservoir conditions such as high temperatures, pressures, and salinity, leading to reduced foam stability and mobility control.
Innovation Solution
The use of specific surfactants, such as lauramidopropylamine oxide and myristamidopropylamine oxide, in combination with brine to generate foams that are stable under harsh reservoir conditions, enhancing oil recovery by forming stable foams that control fluid flow.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Stability of the object's composition
If conventional foam formulations are used, then foam generation is simple, but foam stability deteriorates under high temperatures, pressures, and salinity
Solution Approach 1:
The patent applies parameter changes by modifying the chemical composition parameters of the foam formulation. Specifically, it uses surfactants with optimized hydrophobic and hydrophilic balance, adjusts surfactant concentration ranges, and selects foaming gases with appropriate solubility characteristics to maintain foam stability under high temperature, pressure, and salinity conditions.
Solution Approach 2:
The patent employs composite materials by combining multiple surfactants (anionic, cationic, nonionic, or zwitterionic types) in specific ratios, mixing different foaming gases (CO2, N2, CH4, or hydrocarbon gases), and integrating foam stabilizers. This composite approach creates synergistic effects that enhance foam stability under harsh reservoir conditions compared to single-component formulations.
2Reliability
If conventional surfactants are used, then formulation is straightforward, but mobility control capability deteriorates
Solution Approach 1:
The patent optimizes mobility control by adjusting critical parameters including surfactant concentration (0.01-10 wt%), hydrophobic chain length (C12-C18), and foaming gas composition ratios. These parameter optimizations enable the foam to achieve appropriate viscosity and blocking characteristics for effective mobility control in heterogeneous reservoirs.
Solution Approach 2:
The patent applies local quality by designing surfactant molecules with specific local structural characteristics - such as hydrophobic tail length, hydrophilic head group type, and molecular geometry - that enable the foam to adapt to different reservoir zones with varying permeability and saturation, providing localized mobility control where needed.
3Strength
If conventional foaming gases are used, then gas availability is high, but foam strength deteriorates under reservoir conditions
Solution Approach 1:
The patent adjusts parameters including foaming gas composition (CO2, N2, CH4, or hydrocarbon gases in various ratios), gas injection pressure and temperature, and gas-to-surfactant solution ratio. These parameter changes optimize foam bubble nucleation, growth, and stabilization, producing stronger foam structures that resist collapse under reservoir pressure and temperature conditions.
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 described compositions and methods enable the formation of stable foams that maintain high stability and performance under high temperatures, pressures, and salinities, effectively mobilizing oil from reservoirs with lithological heterogeneity.
Implementation Method 1
a surfactant solution, generating a foam comprising the foaming fluid and the surfactant solution... one or more surfactants comprising a primary foaming agent
Implementation Method 2
Foam has the ability to block and control the channeling of fluids within oil-bearing formations. Moreover, foam has beneficial mobility control characteristics. A foam's mobility control generally refers to the ability of foam to block, divert, or control a flow of fluid from high-permeability to low-permeability regions of formations.
Implementation Method 3
mobilizing oil from the porous rock formation by contacting the porous rock formation with the foam; and collecting at least a portion of the mobilized oil
Data Source
AI summary
Methods and materials for foam production in enhanced oil recovery operations are described herein. More specifically, embodiments of the present disclosure relate to foaming agents, gas mobility control agents for use in porous media, compositions comprising such agents, methods for using such agents, methods for generating foams, and systems for enhanced oil recovery. In an embodiment, a method for recovery of oil from a porous rock formation is provided. The method includes contacting a foaming fluid and a surfactant solution described herein with the porous rock formation, and generating a foam comprising the foaming fluid and the surfactant solution. The method further includes mobilizing oil from the porous rock formation by contacting the porous rock formation with the foam; and collecting at least a portion of the mobilized oil.