Flow Control Device Optimization for Liquid Injection Wells
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Solution Overview
Problem
Liquid injection wells face imbalanced fluid placement due to permeability differences and thief zones, leading to ineffective reservoir drainage and early breakthrough of injected fluid, with current methods relying on manual trial and error for flow control device placement and selection.
Innovation Solution
A numerical algorithm and simulation approach to determine optimal flow control device properties, including placement and sizing, to achieve a desired injection profile by integrating continuity and momentum balance equations, allowing for uniform or targeted injection flow rate distribution.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If manual trial and error methods are used for flow control device placement, then device placement can be achieved, but computational effort is excessive and optimization is inefficient
Solution Approach 1:
The patent replaces manual trial-and-error methods with a numerical algorithm that integrates continuity and momentum balance equations. This computational approach automatically determines optimal flow control device properties, eliminating the need for iterative manual simulations and significantly reducing computational effort while improving optimization efficiency.
Solution Approach 2:
The patent changes the approach from fixed manual placement to dynamic optimization by solving governing equations that account for varying reservoir conditions, permeability differences, and flow rates. This allows the system to adapt flow control device properties to specific reservoir characteristics, achieving optimal placement without extensive trial and error.
2Ease of manufacture
If uniform flow control devices are used along the wellbore, then installation is simplified, but imbalanced fluid placement occurs due to permeability differences
Solution Approach 1:
The patent applies local quality by determining that different flow control device properties are needed at different locations along the wellbore. The numerical algorithm calculates position-specific flow control parameters based on local permeability, pressure, and flow rate conditions, ensuring uniform fluid placement despite varying reservoir properties.
Solution Approach 2:
The patent segments the wellbore into multiple zones with different flow control requirements. By dividing the injection well into discrete sections and optimizing flow control devices for each segment based on local conditions, the system achieves balanced fluid placement while maintaining installation feasibility.
3Reliability
If flow control devices are optimized for specific zones, then fluid placement balance improves, but device complexity and selection difficulty increase
Solution Approach 1:
The patent replaces complex manual device selection processes with a numerical algorithm that automatically determines optimal flow control device properties. The algorithm integrates reservoir engineering principles and flow equations to calculate the precise device characteristics needed at each location, reducing selection complexity while improving placement balance.
Solution Approach 2:
The patent enables the system to self-optimize by using the numerical algorithm to automatically determine flow control device properties based on reservoir conditions. The method performs self-assessment of permeability differences, pressure gradients, and flow rates, then selects appropriate device parameters without requiring extensive external expertise or iterative testing.
Data Source
AI summary
The disclosed embodiments include a method, apparatus, and computer program product for determining optimal flow control device (FCD) properties that would yield to a prescribed shape of the injection flow rate profile. For example, in one embodiment, a computer implemented method is configured to perform the steps of: determining a reference location along a production length of the injection well; determining a reference value equal to the injection flow rate profile at the reference location along the production length of the injection well; defining a target injection profile using the reference value; determining a pressure distribution along the production length of the injection well based on the target injection profile; determining a FCD distribution profile using the target injection profile and the pressure distribution; and determining FCD properties that yields the target injection profile based on the FCD distribution profile.