Downhole Tool Formation Dip Measurement via Effective Penetration Length
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Solution Overview
Problem
Current downhole tools for determining formation dip are complex and costly, often requiring additional components and azimuthal borehole images, which are not always necessary or feasible.
Innovation Solution
A downhole tool with two measurements of different effective penetration lengths (EPLs) is used to detect formation boundaries at varying depths, allowing for the calculation of an apparent formation dip without the need for an azimuthal borehole image, using gamma-gamma density, neutron-gamma density, resistivity, or other suitable measurements.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If additional components and azimuthal borehole images are used to determine formation dip, then measurement accuracy is improved, but device complexity and cost increase
Solution Approach 1:
The patent extracts and eliminates the need for complex azimuthal borehole imaging components while retaining the essential functionality of formation dip measurement. By using only density measurements at two different depths with different effective penetration lengths, the system removes unnecessary imaging hardware and processing complexity, achieving the core measurement function through a simplified approach.
Solution Approach 2:
The patent makes the density measurement tool multi-functional by enabling it to determine formation dip through a novel method using measurements at two different depths. The same density measurement capability, when applied at different effective penetration lengths, serves both traditional density logging and formation dip determination, eliminating the need for separate imaging tools and components.
2Measurement precision
If additional components and azimuthal borehole images are used to determine formation dip, then measurement accuracy is improved, but cost increases
Solution Approach 1:
The patent extracts and eliminates the need for expensive azimuthal borehole imaging components while retaining the essential functionality of formation dip measurement. By using only density measurements at two different depths with different effective penetration lengths, the system removes unnecessary imaging hardware and processing complexity, achieving the core measurement function through a simplified approach.
Solution Approach 2:
The patent makes the density measurement tool multi-functional by enabling it to determine formation dip through a novel method using measurements at two different depths. The same density measurement capability, when applied at different effective penetration lengths, serves both traditional density logging and formation dip determination, eliminating the need for separate imaging tools and components.
3Device complexity
If measurements of different effective penetration lengths are used, then formation dip can be determined without azimuthal imaging, but measurement complexity increases
Solution Approach 1:
The patent changes the measurement parameter from single-depth density measurement to multi-depth density measurement with different effective penetration lengths. By measuring density at two different depths and utilizing the difference in effective penetration lengths, the system can calculate formation dip through mathematical relationships, transforming a complex imaging problem into a simpler parameter-based calculation.
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 simplifies the identification of formation boundaries and formation dip, reducing tool complexity and cost while providing accurate relative angles between the wellbore and formation boundaries, enabling effective location of zones of interest like oil, gas, and water without the need for complex imaging.
Implementation Method 1
using gamma-gamma density, neutron-gamma density, resistivity, or other suitable measurements
Implementation Method 2
using gamma-gamma density, neutron-gamma density, resistivity, or other suitable measurements
Implementation Method 3
using gamma-gamma density, neutron-gamma density, resistivity, or other suitable measurements
Data Source
AI summary
Systems and methods for identifying formation boundaries without necessarily obtaining an azimuthal borehole image are provided. A downhole tool may be placed in a wellbore in a geological formation that has a formation boundary. First and second measurements may be obtained at a number of depths of the wellbore. The first measurement may have a first effective penetration length into the geological formation and the second measurement may have a second effective penetration length into the geological formation different from the first effective penetration length. Thus, the first measurement may detect the formation boundary at a first depth and the second measurement may detect the formation boundary at a second depth. Using a difference between the first depth and the second depth, an apparent relative angle between the wellbore and the formation boundary or an apparent formation dip, or both, may be obtained.