Diverter Assembly Sleeve Actuation for Top-Down Squeeze Cementing
Find Innovative SolutionsGenerate Solutions
Solution Overview
Problem
In oil and gas exploration, existing cementing technologies face challenges in efficiently performing top-down squeeze cementing operations to isolate wellbores and set tools like liner hangers, particularly in scenarios where additional cement is needed above previously cemented zones or to meet regulatory requirements.
Innovation Solution
A diverter assembly is introduced that allows for the diversion of cement slurry from a work string to the annulus between the wellbore wall and the string, enabling top-down cementing while also facilitating the setting of tools like liner hangers, using a combination of sleeves, shear pins, and balls to control fluid flow and pressure differentials.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Adaptability or versatility
If a diverter assembly with multiple sleeves and shear pins is used to enable top-down squeeze cementing, then the ability to divert cement slurry and set tools is improved, but the device complexity increases
Solution Approach 1:
The diverter assembly is divided into multiple functional segments including a tubing segment with apertures, a first sleeve with second apertures, and a second sleeve with third apertures. Each segment can be independently positioned to control cement slurry flow paths, enabling versatile operations while maintaining modular construction that manages complexity.
Solution Approach 2:
The diverter assembly is designed to perform multiple functions: diverting cement slurry to the annulus for squeeze cementing, setting liner hangers through controlled pressure differentials, and isolating wellbore zones. The same assembly structure enables both cement diversion and tool setting operations without requiring separate devices.
2Ease of operation
If frangible fasteners are used to couple sleeves to allow pressure differential actuation, then the ease of operation is improved, but the reliability decreases due to potential premature failure
Solution Approach 1:
The frangible fasteners are designed with specific structural parameters including thickness, material composition, and geometric configuration that determine their failure thresholds. By carefully selecting these parameters, the fasteners can withstand normal operating pressures while failing reliably at predetermined pressure differentials during intended actuation events.
Solution Approach 2:
The system incorporates pressure differential feedback through the frangible fastener design, where the fastener remains intact under normal conditions and fails only when the pressure differential reaches a predetermined threshold. This provides inherent feedback control that prevents premature failure while enabling automatic actuation when needed.
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 top-down squeeze cementing operations and tool setting by diverting cement slurry effectively and controlling fluid flow, ensuring proper isolation and tool actuation, thereby enhancing wellbore integrity and compliance with regulatory standards.
Implementation Method 1
a frangible fastener operable to fail upon a pressure differential across the seal reaching a predetermined threshold
Implementation Method 2
a first sealing seat operable to form a seal across a sleeve bore when engaged by an occluding member
Data Source
AI summary
A diverter assembly includes a tubing segment and one or more sleeve members disposed therein. The tubing segment includes apertures that are selectively alignable with apertures of an inner sleeve disposed within the tubing segment. The tubing segment includes a series of stops (e.g., shear pins) to arrest movement of the first sleeve within the bore of the tubing segment. A first one or more ball seats are included in the first sleeve such that deployment of a first ball and pressurization of the well above the first ball causes a first set of shear pins to fail, thereby allowing the first sleeve to slide downhole to cause apertures of the sleeve to align with apertures of the tubing segment, thereby causing fluid to flow to an annulus between the tubing segment and wellbore wall.