Gas Injection Composition Assessment for EOR Corrosion Control
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Solution Overview
Problem
Gas injection in field operations for enhanced oil recovery (EOR) faces challenges due to acidic gas components like CO2 and H2S, which affect in-situ water chemistry and rock properties, leading to issues such as corrosion, scale accumulation, and reduced hydrocarbon recovery.
Innovation Solution
A method and system for assessing potential injection gases based on fluid chemistry parameters and rock properties to determine a proposed injection gas that minimizes adverse effects, optimizing gas composition and concentration to improve EOR performance and extend well life.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If acidic gas (CO2, H2S) is injected for enhanced oil recovery, then hydrocarbon recovery is improved, but corrosion and scale accumulation occur
Solution Approach 1:
The system performs preliminary assessment of injection gas composition against formation water chemistry and rock properties before gas injection begins. By evaluating parameters such as pH change, scale deposition potential, and corrosion risk in advance, the system selects optimal gas composition that minimizes harmful effects while maintaining EOR effectiveness
Solution Approach 2:
The system optimizes the composition parameters of the injection gas by adjusting the concentration and type of acidic components (CO2, H2S) based on formation characteristics. This parameter optimization allows achieving hydrocarbon recovery goals while controlling corrosion and scale accumulation through balanced gas composition
2Productivity
If acidic gas injection is performed to enhance oil recovery, then production efficiency increases, but well life is reduced
Solution Approach 1:
The system conducts preliminary evaluation of rock properties and water chemistry to predict long-term effects of gas injection on well integrity. By assessing formation characteristics before injection, the system determines optimal gas composition that extends well life while maintaining production efficiency
Solution Approach 2:
The system converts potentially harmful acidic gas components into beneficial agents for EOR by carefully controlling their concentration and composition. The optimized gas mixture enhances oil recovery while the controlled acidity actually improves porosity and permeability without causing excessive corrosion or scale, thereby extending well life
3Reliability
If gas composition is optimized to reduce corrosion, then well integrity is improved, but hydrocarbon recovery may be reduced
Solution Approach 1:
The system performs multi-parameter optimization of gas composition, simultaneously considering corrosion risk, scale deposition potential, and EOR effectiveness. By adjusting parameters such as CO2 and H2S concentrations based on formation water chemistry and rock properties, the system achieves balanced outcomes that maintain well integrity while ensuring adequate hydrocarbon recovery
Solution Approach 2:
The system uses assessment results from evaluating multiple potential injection gases against formation parameters to determine the optimal gas composition. This feedback-driven selection process ensures that the chosen gas mixture balances well integrity protection with hydrocarbon recovery enhancement
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 approach enhances hydrocarbon recovery by reducing scale deposition and corrosion, increasing porosity and permeability, and extending the life of injection wells, while also trapping acidic gases like CO2, thereby improving overall field operation efficiency.
Implementation Method 1
The acidic gas may have an impact on in situ water chemistry and water-rock/material interactions
Data Source
AI summary
A method of improving a field operation that comprises a gas injection may include assessing a plurality of potential injection gases against a plurality of values of a plurality of parameters associated with a plurality of samples, where each of the plurality of potential injection gases comprises an acidic component, and where the plurality of parameters comprises fluid chemistry parameters and rock properties. The method may also include determining a proposed injection gas from among the plurality of potential injection gases for the field operation that comprises the gas injection to be performed using a first wellbore in fluidic communication with a first subterranean formation, a second wellbore in fluidic communication with the first subterranean formation, a third wellbore in fluidic communication with a second subterranean formation, or any combination thereof.