Closed-Loop Hydraulic Running Tool Actuation
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Solution Overview
Problem
Existing running tools for wellbore members face challenges in deepwater operations due to difficulties in precise rotation and actuation, particularly with hydraulic lines and wellbore fluid pressure, which can be time-consuming and costly, and may be impaired by clogging or fouling.
Innovation Solution
A running tool that uses a closed-loop hydraulic system actuated by external pressure through a blow-out preventer (BOP) stack and running string, eliminating the need for control lines and relying on low-pressure fluid pressure to move pistons and actuate the tool, allowing for precise positioning and locking of wellbore members without umbilical lines.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Ease of operation
If hydraulic lines are deployed through the riser to the running tool, then the running tool can be actuated, but the operation requires more time and expense for running or retrieval operations
Solution Approach 1:
The invention extracts and eliminates the hydraulic lines and control mechanisms from the running tool system. Instead of using hydraulic lines deployed through the riser, the tool is actuated by the runner rotating the running string itself, which directly drives the running tool without requiring separate control lines or umbilicals.
Solution Approach 2:
The running string serves multiple functions: it not only transports the running tool to the wellbore but also acts as the actuation mechanism itself. The rotation of the running string during running operations directly powers the running tool, eliminating the need for dedicated hydraulic control lines.
2Ease of operation
If hydraulic lines are deployed through the riser to the running tool, then the running tool can be actuated, but the operation requires more expense for running or retrieval operations
Solution Approach 1:
The invention removes the expensive hydraulic line infrastructure from the system. By eliminating hydraulic lines, control darts, and associated umbilicals, the operation reduces equipment costs, deployment complexity, and retrieval expenses.
Solution Approach 2:
The running tool actsuates itself using the rotational energy already present in the running string during normal running operations. This self-actuation capability eliminates the need for separate expensive control systems and reduces operational expenses.
3Ease of operation
If wirelines are used to actuate the running tool, then the running tool can be controlled, but wirelines add time and expense to the operation
Solution Approach 1:
The invention replaces the wireline mechanical control system with a direct rotational mechanical drive. Instead of using wirelines to transmit control signals, the rotation of the running string directly actuates the running tool through mechanical connection, eliminating the intermediate wireline control mechanism.
4Adaptability or versatility
If wellbore fluid pressure is used to actuate running tools, then the running tool can be operated without control lines, but the wellbore fluid can clog or foul the running tool
Solution Approach 1:
The invention extracts the running tool actuation mechanism from the wellbore fluid environment. By using the rotation of the running string (which is outside the wellbore) to actuate the tool, the system eliminates the need for wellbore fluid to contact or power the running tool, preventing clogging and fouling.
Solution Approach 2:
The running string acts as an intermediary that transfers rotational energy from the surface equipment to the running tool without requiring direct contact with wellbore fluids. This intermediary mechanism allows actuation while maintaining separation from the potentially contaminating wellbore environment.
5Ease of operation
If rotation is used to actuate the running tool, then the running tool can be operated without control lines, but it can be difficult to transmit a precise amount of rotation through a long riser assembly
Solution Approach 1:
The invention segments the rotation transmission system into discrete, mechanically connected components along the running string. This segmentation with direct mechanical coupling ensures that rotation is transmitted precisely from the surface through the running string to the running tool without the cumulative errors that occur in long, flexible riser assemblies.
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
Enables efficient and cost-effective operation of running tools in deepwater environments by using existing wellbore fluids to actuate the tool, reducing the risk of clogging and fouling, and allowing for precise placement and release of wellbore members without the need for hydraulic lines or rotation, thus enhancing operational efficiency and safety.
Implementation Method 1
The running tool components can be actuated by providing external pressure through a blow-out preventer ('BOP') stack and pressure through the running string
Implementation Method 2
When the fluid pressure moves the outer piston down, the outer piston creates pressure in a closed-loop hydraulic system
Implementation Method 3
The action/fluid pressure of the actuation sleeve and latch moving upwards forces fluid through the closed-loop hydraulic system and, in response, strokes the inner piston upwards
Data Source
AI summary
A method and apparatus for setting an inner wellhead member in a subsea wellhead housing includes connecting an inner wellhead member to a running tool and running the running tool and wellhead member through a tubular member to a wellhead housing. A plurality of pistons urge fluid through a closed-loop hydraulic system. That fluid actuates a locking mechanism to lock the inner wellhead member into the wellhead housing, and also actuates a release mechanism to release the running tool from the inner wellhead member. The pistons are moved from one position to another in response to fluid pressure from the running string to which the running tool is connected, fluid pressure from the tubular member in which the running tool is located, or in response to fluid in the closed-loop hydraulic system that is being moved in response to the other one of the pistons.