CO2 EOR Gas Phase Compression and Injection
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Solution Overview
Problem
Existing CO2 EOR methods face challenges in offshore applications due to complex and costly CO2 separation processes, particularly in managing dynamic CO2 content and hydrate formation, which complicates equipment operation and material selection in offshore oil fields.
Innovation Solution
A method involving the separation of well streams into liquid and gas phases, where the entire gas phase, comprising both CO2 and hydrocarbons, is compressed and mixed with external CO2 for injection into the reservoir, avoiding the need for complex CO2 separation and reducing hydrate formation risks through controlled cooling and condensation.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Quantity of substance
If CO2 is separated from the gas phase using membrane separators or other separation technologies, then CO2 can be obtained for injection, but the process becomes complex and expensive
Solution Approach 1:
The patent extracts only the essential component (CO2) from the well stream by separating the gas phase from the liquid phase, then directly injecting the separated CO2 without requiring complex further separation processes. This simplifies the overall system while achieving the desired CO2 concentration for effective EOR injection.
Solution Approach 2:
The patent segments the well stream into distinct liquid and gas phases using gas/liquid separators, allowing the CO2-rich gas phase to be independently processed and injected. This segmentation avoids the need for complex continuous separation processes while effectively concentrating CO2 for injection.
2Adaptability or versatility
If CO2 content in the gas phase is highly dynamic (from a few mole % to 80-90 mole %), then the EOR process can adapt to varying reservoir conditions, but separation technologies become difficult to apply
Solution Approach 1:
The patent employs dynamic gas/liquid separators that can adapt to varying CO2 concentrations in the well stream. The separators automatically adjust their operation based on the real-time composition of the well stream, maintaining effective separation across the full range of CO2 content variability without requiring complex control systems or multiple separation technologies.
3Ease of operation
If the gas phase is cooled to prevent hydrate formation, then equipment operation is simplified, but energy consumption increases
Solution Approach 1:
The patent converts the potentially harmful effect of cooling (energy consumption) into a beneficial outcome by utilizing the cooling process to simultaneously prevent hydrate formation and prepare the CO2 for efficient injection. The cooling serves dual purposes: operational safety and process optimization, reducing net energy penalty.
4Productivity
If CO2 is injected into the reservoir for EOR, then oil recovery rate increases by 5-15 percentage points, but operational complexity and costs increase
Solution Approach 1:
The patent merges the CO2 separation, compression, and injection functions into an integrated system that leverages existing offshore oil field infrastructure. By combining these functions and utilizing available facilities, the system achieves effective CO2 EOR injection while minimizing additional operational complexity and capital investment.
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 simplifies the CO2 EOR process, reduces operational complexity and costs, and is particularly effective in offshore environments by utilizing the entire gas phase for injection, thereby enhancing oil recovery while minimizing equipment and material challenges.
Implementation Method 1
separating the well stream into a liquid phase and a gas phase with a first gas/liquid separator, wherein the gas phase comprises both CO2 gas and hydrocarbon gas
Implementation Method 2
cooling the gas phase with a first cooler
Implementation Method 3
reducing hydrate formation risks through controlled cooling and condensation
Implementation Method 4
compressing the gas phase using a first compressor into a compressed stream
Implementation Method 5
injecting the injection stream into the reservoir
Data Source
AI summary
Methods of Enhanced Oil Recovery (EOR) from an oil reservoir by CO2 flooding are disclosed. One method comprises producing a well stream from the reservoir; separating the well stream into a liquid phase and a gas phase with a first gas/liquid separator, wherein the gas phase comprises both CO2 gas and hydrocarbon gas; cooling the gas phase with a first cooler; compressing the gas phase using a first compressor into a compressed stream; mixing the compressed stream with an external source of CO2 to form an injection stream; and injecting the injection stream into the reservoir. Systems for EOR from an oil reservoir by CO2 flooding are also disclosed.