Top-Down Fracturing Valve Actuation for Multi-Zone Wellbores
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Solution Overview
Problem
Current hydraulic fracturing systems for wellbores, such as those using ball-actuated sliding sleeves, face limitations in the number of production zones due to the need for varying size balls and high pressure fluids, which complicates operations and can result in issues like stuck balls and incomplete fracturing.
Innovation Solution
A valve system with a sliding closure member and lock rings that allows selective actuation between open and closed positions using a coiled tubing actuation tool, enabling efficient and controlled fluid communication in wellbores, reducing the complexity and cost of fracturing operations.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Adaptability or versatility
If ball-actuated sliding sleeves are used for hydraulic fracturing, then production zones can be created, but the number of production zones is limited due to the need for varying size balls and high pressure fluids
Solution Approach 1:
The sliding sleeve valve is designed to accept actuation by a single standardized coiled tubing tool regardless of the production zone depth or number. The valve mechanism itself remains universal while the actuation method adapts to different zones through the same tool, eliminating the need for multiple specialized balls of varying sizes.
Solution Approach 2:
The system changes the actuation parameter from requiring different sized balls for different zones to using a single ball size with controlled injection pressure. The differentiation between zones is achieved through pressure parameters and sequential injection timing rather than physical ball size variations.
2Adaptability or versatility
If varying size balls are used to actuate sliding sleeves, then different production zones can be accessed, but operational issues such as stuck balls and incomplete fracturing occur
Solution Approach 1:
The system uses identical sliding sleeve valve designs throughout the wellbore, all actuated by the same standardized coiled tubing tool. This homogeneity in design and actuation mechanism eliminates the reliability issues associated with varying ball sizes, as there is only one ball design and one actuation method to master.
Solution Approach 2:
The system replaces the mechanical ball-sleeve interaction with a hydraulic injection mechanism. Instead of relying on mechanical engagement of balls with varying sizes, the system uses fluid pressure injection through the coiled tubing to actuate the sliding sleeves, reducing mechanical wear and sticking issues.
3Adaptability or versatility
If high pressure fluids are used to actuate sliding sleeves, then production zones can be created, but the system requires complex high pressure equipment and increases operational risk
Solution Approach 1:
The coiled tubing tool serves as an intermediary delivery mechanism for the actuation fluid. Instead of requiring complex high-pressure surface equipment, the system uses the coiled tubing itself as the pressure delivery system, injecting fluid directly at the downhole valve location through simple injection ports.
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 solution allows for the creation of multiple production zones with reduced operational complexity and increased efficiency, enabling effective hydraulic fracturing across a wellbore without the need for multiple balls, thus enhancing fluid flow and reducing the risk of tool sticking.
Implementation Method 1
in response to receipt of a predetermined volume of high pressure fluid through the valve from the coiled tubing actuation tool, the closure member is configured to actuate from the closed position to the open position
Implementation Method 2
a seal restricting fluid flow between the high pressure fluid chamber and the low pressure fluid chamber when the closure member is in the closed position
Implementation Method 3
enabling efficient and controlled fluid communication in wellbores, reducing the complexity and cost of fracturing operations
Data Source
AI summary
A flow transported obturating tool for actuating a valve in a wellbore includes a housing including a first engagement member and a second engagement member, wherein the first and second engagement members each include an unlocked and a locked position, and a core disposed in the housing, wherein the core is configured to actuate both the first engagement member and the second engagement member between the unlocked and locked positions, wherein, when the first engagement member is in the locked position, the first engagement member is configured to locate the obturating tool at a predetermined axial position in the valve, wherein, when the second engagement member is in the locked position, the second engagement member is configured to shift the valve from an open position to a closed position.