Slim-Hole Test Packer for Tight Reservoirs
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Solution Overview
Problem
Current well testing practices in subterranean formations, especially in tight and unconventional reservoirs, face challenges such as high rig static time and costs due to the need for large wellbores and complex equipment setups, which can lead to inaccurate data collection and misclassification of wells as 'dry' or uneconomical, even when hydrocarbons are present.
Innovation Solution
A fast-setting retrievable slim-hole test packer system designed for use in 4½″ liners, allowing fluid flow in the annulus rather than the inner bore, enabling efficient data capture and reducing the need for 4½″ tubing, thus minimizing costs and rig time, and incorporating a movable sleeve and packer assembly for precise zone isolation and fluid sampling.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Volume of stationary object
If a large wellbore storage factor is used (4½″ cemented liner), then the well can accommodate complex testing equipment, but the wellbore storage effect increases and makes it difficult to detect limited hydrocarbon flow
Solution Approach 1:
The invention extracts the packer and shut-in tool functions into a single integrated downhole assembly that can be deployed in slim-hole completions. This eliminates the need for large wellbore storage capacity by performing both zonal isolation and pressure containment at the test location, thereby reducing wellbore storage effects while maintaining the ability to detect limited hydrocarbon flow in tight and unconventional reservoirs
2Reliability
If traditional well testing methods are used with separate shut-in tool and packer, then zonal isolation can be achieved, but the device complexity increases and requires multiple trips
Solution Approach 1:
The invention merges the packer and shut-in tool into a single integrated downhole assembly. The packer sets to provide zonal isolation, and the shut-in tool is positioned within the packer assembly to provide pressure containment. This combination eliminates the need for separate deployment of multiple tools, reducing device complexity and enabling one-trip testing operations while maintaining reliable zonal isolation
3Ease of operation
If 4½″ tubing is installed for well completion, then the well can handle testing operations, but the manufacturing cost and rig time increase
Solution Approach 1:
The invention employs a dynamic, movable sleeve within the downhole assembly that can transition between open and closed positions to control fluid flow paths. This dynamic mechanism allows the system to perform multiple functions (flow testing, pressure containment, fluid sampling) through a single deployment, eliminating the need for permanent 4½″ tubing installation and reducing well completion costs while maintaining full testing operation capability
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 enables more efficient and cost-effective well testing by eliminating wellbore storage effects, allowing real-time data capture, and simplifying well completion, thereby improving the detection and development of tight and unconventional reservoirs.
Implementation Method 1
a packer assembly to seal an annulus between the middle sleeve and an inner diameter of the slim-hole
Implementation Method 2
A shear-screw extends radially through the outer housing and into the middle sleeve. The shear-screw is selectively sheared to move the assembly to the retrieval position
Data Source
AI summary
A well test assembly sized for use in a slim-hole of a subterranean well includes an inner moveable sleeve having an inner circulation port and an inner fluid passage port. An outer housing has a first outer circulation port, an outer fluid passage port, and a second outer circulation port. A middle sleeve has: a middle circulation port aligned with the inner circulation port and the first outer circulation port when the assembly is in a lowering position; a middle fluid passage aligned with the inner fluid passage port and the outer fluid passage port when the assembly is in a collection position; and a fluid injection port aligned with the second outer circulation port when the assembly is in a retrieval position. A packer assembly seals an annulus between the middle sleeve and an inner diameter of the slim-hole when the assembly is in a setting position.