Rotary Steerable Trajectory Advising for Collision-Aware Wellbore Control
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Solution Overview
Problem
Existing directional drilling techniques face challenges in maintaining precise control over drilling trajectories, especially in complex formations, leading to inefficiencies and potential collisions, particularly when using rotary steerable systems.
Innovation Solution
A system and method for controlling the drilling trajectory of a downhole tool using a computing system that includes a planning platform, execution platform, and downhole platform, which utilize predictive models, real-time data, and sensors to adjust drilling plans dynamically, ensuring accurate trajectory alignment and collision avoidance.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Measurement precision
If conventional directional drilling techniques are used with bend near the bit in a downhole steerable mud motor, then the bit can be pointed in a direction different from the axis of the wellbore, but the drilling operation struggles to maintain precise control over drilling trajectories in steeply dipping formations and unpredictable deviations
Solution Approach 1:
The patent implements dynamic adjustment of drilling parameters (weight on bit, rotary speed, mud flow rate) in real-time based on measured trajectory deviations and formation characteristics. The system continuously adapts steering commands to maintain precise trajectory control in varying formation conditions, transitioning from static pre-planned trajectories to dynamic real-time trajectory optimization.
Solution Approach 2:
The system employs real-time feedback loops where measured drilling trajectory data is continuously compared against the planned trajectory, and deviation signals are used to adjust steering commands. This closed-loop control system processes measured depth, inclination, azimuth, and formation properties to generate corrected steering instructions that maintain precise trajectory control.
2Productivity
If the entire drillstring is rotated to maintain wellbore direction, then the bit sweeps around and its net direction coincides with the existing wellbore, but the rate of penetration decreases compared to non-rotating steering methods
Solution Approach 1:
The patent implements periodic rotation of the drillstring at optimized speeds and intervals, rather than continuous rotation. The system determines optimal rotation periods based on formation properties and trajectory requirements, allowing the bit to sweep through multiple directions periodically while maintaining overall trajectory accuracy and improving rate of penetration compared to continuous rotation.
Solution Approach 2:
The system dynamically adjusts between rotating and non-rotating drilling modes based on real-time trajectory deviations and formation conditions. When trajectory control is critical, the system minimizes rotation; when rate of penetration is prioritized and formations allow, the system increases rotation frequency, optimizing the balance between productivity and trajectory precision.
3Reliability
If directional drilling techniques are employed to ensure vertical drilling in steeply dipping formations, then the wellbore can be maintained vertically, but the complexity of adjusting drilling parameters and steering commands increases significantly
Solution Approach 1:
The patent implements automated steering command generation and drilling parameter optimization systems that self-adjust based on measured trajectory data and formation properties. The system automatically calculates required steering corrections, determines optimal weight on bit and rotary speed settings, and executes adjustments without requiring complex manual intervention, reducing operational complexity while maintaining reliable vertical alignment.
Solution Approach 2:
The system integrates multiple functions into a unified control platform that simultaneously handles trajectory measurement, formation property analysis, steering command generation, and drilling parameter optimization. This multi-functional integration consolidates what would otherwise be separate complex control systems into a single coordinated platform, reducing overall operational complexity.
4Adaptability or versatility
If the drilling plan is strictly followed without real-time adjustments, then the planned trajectory is maintained, but the system cannot adapt to measured deviations or optimize placement in productive reservoir rock
Solution Approach 1:
The patent implements continuous real-time trajectory monitoring and adjustment processes that operate throughout the entire drilling operation. Rather than periodic or post-drilling corrections, the system continuously measures trajectory, compares with plan, calculates deviations, and applies corrections in real-time, ensuring continuous adaptation to measured deviations and optimal reservoir placement without interrupting the drilling process.
Solution Approach 2:
The system performs preliminary analysis of formation properties and trajectory deviations as they are encountered, predicting optimal steering corrections and parameter adjustments before significant deviations occur. This proactive approach allows the system to make timely adjustments that prevent large trajectory errors rather than correcting them after they develop, reducing the time lost to trajectory corrections.
Data Source
AI summary
A method for controlling a drilling trajectory of a downhole tool includes receiving a drilling plan for a downhole tool to drill a wellbore toward a target in a subterranean formation. The method also includes receiving a measured drilling trajectory of the downhole tool after the downhole tool drills a first portion of the wellbore using the planned drilling trajectory. The method also includes determining a state of the downhole tool based at least partially upon the planned drilling trajectory and the measured drilling trajectory. The state includes a difference between the planned drilling trajectory and the measured drilling trajectory, a level of control of a steering capability of the downhole tool, and a location of an end of the wellbore. The method also includes generating a working plan trajectory based at least partially upon the state of the downhole tool and the drilling plan.