Flow Control Device Optimization for Uniform Flooding in Injection Wells
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Solution Overview
Problem
Current methods for determining the optimal placement and properties of flow control devices (FCDs) in liquid injection wells for oil recovery rely on manual trial and error, lacking a systematic approach to achieve uniform fluid flux and prevent premature breakthrough of injected fluid due to frictional pressure drops and reservoir permeability variations.
Innovation Solution
A numerical algorithm and simulation process that calculates the optimal placement and properties of FCDs, such as hole sizes and distribution, to ensure a uniform flooding front along the wellbore, using a coupled reservoir-wellbore hydrodynamic model and optimizing the FCD distribution function to compensate for pressure drops and formation heterogeneities.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Productivity
If manual trial and error methods are used to determine FCD placement and properties, then flexibility in exploring different configurations is maintained, but the process is inefficient and lacks systematic optimization
Solution Approach 1:
The patent replaces manual trial-and-error mechanical optimization with a numerical algorithm that uses computational methods to systematically determine optimal FCD placement and properties. The algorithm calculates flow distribution and iteratively adjusts FCD parameters to achieve uniform fluid flux, substituting human manual processes with automated computational analysis.
Solution Approach 2:
The numerical algorithm performs self-optimization by automatically calculating the optimal FCD configuration based on reservoir and wellbore parameters. The system serves itself by using built-in computational logic to iterate through possible solutions and converge on the optimal placement and properties without external manual intervention.
2Manufacturing precision
If FCDs are placed to compensate for frictional pressure drops and permeability variations, then uniform fluid flux is achieved, but the device configuration becomes more complex
Solution Approach 1:
The patent applies local quality by varying FCD properties (such as flow coefficients or restrictions) at different locations along the wellbore to compensate for local variations in frictional pressure drops and reservoir permeability. Each FCD is customized for its specific position to achieve uniform overall flux distribution, rather than using identical standardized devices throughout.
Solution Approach 2:
The numerical algorithm systematically changes FCD parameters (flow coefficients, restrictions, placement positions) to optimize fluid flux distribution. The method involves iteratively adjusting these parameters based on calculated pressure drops and permeability variations, transforming the optimization process into a systematic parameter tuning exercise rather than random configuration.
3Loss of time
If numerical algorithms are used to optimize FCD properties, then computational efficiency is improved, but the requirement for complex hydrodynamic modeling increases
Solution Approach 1:
The patent segments the complex reservoir-wellbore system into manageable computational components, including the wellbore flow domain and reservoir flow domain, which are modeled separately but coupled together. This segmentation allows the numerical algorithm to efficiently handle the hydrodynamic calculations by breaking down the overall complex model into discrete solvable segments.
Solution Approach 2:
The numerical algorithm acts as an intermediary that bridges the complex hydrodynamic model and the optimization objective. It translates reservoir and wellbore parameters into FCD configuration recommendations, mediating between the complex physical system and the practical optimization goal, thereby managing complexity through systematic computation.
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 solution enables a uniform displacement front towards the production well, maximizing oil recovery and reducing the risk of premature breakthrough, with computational efficiency and flexibility to handle varying complexity levels in wellbore-reservoir simulations.
Implementation Method 1
causes a pressure drop between the wellbore and a reservoir to reduce flow between the wellbore and the reservoir at the location of the flow control device
Data Source
AI summary
The disclosed embodiments include a computer implemented method, apparatus, and computer program product that includes executable instructions that when executed performs operations for determining flow control device (FCD) properties for an injection well that yields uniform flooding along the production well.