Autonomous Valve Flow Control in Branched Wells
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Solution Overview
Problem
Existing systems for oil and gas production in highly permeable geological formations face issues such as increased pressure in drainage pipes due to flow friction, leading to reduced oil and gas flow, and a high risk of coning, where unwanted water or gas enters the pipe, and are unable to distinguish and control the inflow of different fluid qualities like oil, gas, and water effectively.
Innovation Solution
The implementation of autonomous valves with a movable disc that adjusts based on fluid viscosity, using the principle that the sum of static pressure, dynamic pressure, and friction is constant along a flow line, allowing for controlled flow by varying the flow path according to fluid properties, and integrating these valves into the production pipe to manage fluid flow and prevent coning.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Adaptability or versatility
If autonomous valves with movable disc are used to control flow based on fluid viscosity, then the ability to distinguish and control different fluid qualities (oil, gas, water) is improved, but the device complexity increases
Solution Approach 1:
The autonomous valve uses the fluid's own properties (viscosity, phase) to automatically control its own flow without external intervention. The movable disc responds passively to fluid characteristics, allowing the device to self-regulate based on whether oil, gas, or water is present, eliminating the need for complex sensors or control systems
Solution Approach 2:
The valve exploits changes in fluid physical parameters (particularly viscosity and phase) to trigger flow control. Different fluids create different pressure distributions across the movable disc, automatically adjusting the flow path based on the fluid's inherent properties rather than requiring active detection mechanisms
2Productivity
If the production pipe is divided into sections with inflow restriction devices, then the inflow rate control is improved, but the flow turbulence increases and work-over tools cannot be run
Solution Approach 1:
The valve provides dynamic flow control that adapts to changing conditions without creating fixed restrictions. The movable disc adjusts the flow path continuously based on real-time fluid properties, maintaining laminar flow conditions that allow work-over tools to pass through while still controlling inflow rates effectively
3Productivity
If the drainage pipe diameter is increased to reduce flow friction, then the oil and gas flow increases, but the risk of coning increases due to greater velocity
Solution Approach 1:
The valve applies local flow control at different locations along the production pipe. By adjusting the flow path restriction locally based on fluid properties, it reduces velocity in vulnerable sections to prevent coning while maintaining adequate flow capacity in other sections, creating a balanced flow distribution throughout the system
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 maintains a constant volume rate and effectively filters phases, enhancing oil and gas production by preventing unwanted fluid entry and optimizing flow through each section of the well, resulting in increased reservoir drainage and production efficiency.
Implementation Method 1
using the principle that the sum of static pressure, dynamic pressure, and friction is constant along a flow line
Implementation Method 2
autonomous valves with a movable disc that adjusts based on fluid viscosity
Implementation Method 3
effectively filters phases, enhancing oil and gas production by preventing unwanted fluid entry
Data Source
AI summary
A system and a method for controlling the flow of fluid in a branched well from a reservoir (29), the system including a completed main well (27) having at least one uncompleted branch well (25), an annulus (24) defined between the reservoir (29) and a production pipe (1) of the completed main well (27) and at least two successive swell packers or constrictors (26) defining at least one longitudinal section of the main well (27) and within which at least one branch well (25) is arranged, and including at least one autonomous valve (2) arranged in the longitudinal section of the main well (27) defined between the two successive swell packers or constrictors (26). The uncompleted branch wells (25) are provided to increase the drainage area, i.e., maximum reservoir contact (MRC).