Downhole Pipe Inspection Tool Configuration Optimization
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Solution Overview
Problem
Existing electromagnetic logging techniques for hydrocarbon exploration face challenges in accurately inspecting nested downhole pipes due to varying well diagrams, leading to suboptimal tool configurations and deteriorated data quality, as they require different numbers of sensors and logging speeds for each well, resulting in inaccurate sensitivity, accuracy, and vertical resolution.
Innovation Solution
The use of two-dimensional electromagnetic forward modeling to generate synthetic logs and construct non-linear mapping functions between one-dimensional and two-dimensional models, allowing for the computation of quasi-2D logs and model-based inversion to estimate pipe parameters, thereby optimizing tool performance metrics and adjusting tool parameters for improved data quality.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If a fixed number of sensors and logging speed are used for electromagnetic pipe inspection, then the tool configuration is simple, but the data quality deteriorates when the well diagram varies
Solution Approach 1:
The patent implements dynamic tool configuration where the number of sensors activated and logging speed are adjusted in real-time based on the detected well diagram and pipe nesting configuration. The system transitions from static to dynamic sensor array activation, enabling optimal data quality for varying well conditions without requiring a fixed complex configuration for all scenarios.
Solution Approach 2:
The system changes operational parameters (number of active sensors, logging speed) based on the well diagram characteristics. By detecting the pipe configuration and adjusting these parameters dynamically, the system achieves high measurement precision across different well conditions without requiring maximum complexity in all cases.
2Measurement precision
If the number of sensors is increased to detect all pipes in one run, then the measurement coverage is improved, but the tool complexity and operation time increase
Solution Approach 1:
The patent segments the sensor array into multiple groups that can be selectively activated based on the pipe nesting configuration. Instead of activating all sensors simultaneously, the system divides and activates only the necessary sensor groups for the current well diagram, reducing operation time while maintaining complete pipe detection coverage.
Solution Approach 2:
The system applies partial action by activating only the necessary number of sensors required for the current well configuration rather than all available sensors. This selective activation maintains measurement coverage while significantly reducing operation time and resource consumption.
3Productivity
If logging speed is increased to improve productivity, then the operation time is reduced, but the signal-to-noise ratio deteriorates
Solution Approach 1:
The patent implements dynamic logging speed adjustment where the speed is adaptively changed based on the well diagram complexity and pipe nesting configuration. The system transitions from fixed-speed logging to variable-speed logging, maintaining high signal-to-noise ratio in complex configurations while achieving faster logging in simpler well diagrams.
4Measurement precision
If general estimation of tool specifications is used, then the setup process is simple, but the sensitivity, accuracy, and vertical resolution are inaccurate for specific wells
Solution Approach 1:
The patent performs preliminary well diagram analysis and tool configuration optimization before the actual inspection operation. By pre-processing the well diagram data and determining optimal sensor activation patterns and logging speeds in advance, the system achieves high measurement precision without adding complexity to the execution phase.
Solution Approach 2:
The system uses feedback from well diagram analysis to automatically adjust tool specifications and configuration parameters. The feedback loop takes well-specific characteristics as input and outputs optimized configuration settings, eliminating the need for manual general estimation and ensuring accurate sensitivity, accuracy, and vertical resolution for each specific well.
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 enables precise tool specifications and optimal configurations for each well, enhancing data quality, reducing operation time and costs by providing accurate sensitivity, signal-to-noise ratio, and vertical resolution, and improving the accuracy of pipe thickness estimation.
Implementation Method 1
when the transmitter coil emits the primary transient EM fields, eddy currents are induced in the casing
Implementation Method 2
eddy currents are induced in the casing. These eddy currents then produce secondary fields which are received along with the primary fields by the receiver coil
Data Source
AI summary
Electromagnetic logging tools are optimized using synthetic logs for the purpose of pre-job planning and accuracy/resolution estimation. One, two and three-dimensional forward modeling are used to generate accurate inspection tool responses. A radial one-dimensional (R1D) electromagnetic forward model is also used to compute an approximate log. By constructing non-linear mapping functions between the R1D model-based log and the 2D model-based log, and mapping the R1D synthetic log using the non-linear mapping functions, a quasi 2D log is computed. The quasi 2D log is processed using model-based inversion, thereby providing estimates of pipe parameters. By analyzing the estimates of pipe parameters, tool performance metrics are obtained and analyze to determine the performance of the tool. The tool parameters are adjusted in order to optimize the performance metrics.