Top Drive Slide Drilling Oscillation Control
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Solution Overview
Problem
During slide drilling operations, the reduced weight-on-bit due to axial friction between the drill string and the wellbore sidewall results in a lower rate of penetration, reducing the efficiency of well construction processes.
Innovation Solution
Implementing a top drive system with a rotation sensor and processing device that imparts rotational oscillations in alternating directions to the drill string, maintaining downhole toolface orientation while adjusting the rotational distance to optimize weight transfer and penetration rate.
Engineering Contradictions & Design Principles
Engineering Contradiction Analysis
1Ease of operation
If slide drilling is performed with the drill string sliding along the wellbore sidewall, then the drill string weight is reduced due to axial friction, but the rate of penetration decreases due to reduced weight-on-bit
Solution Approach 1:
The patent applies mechanical vibration by imparting rotational oscillations to the drill string through the top drive system. These oscillations create dynamic motion that reduces axial friction between the drill string and wellbore sidewall, allowing weight-on-bit to be maintained or increased while still enabling smooth drill string movement during slide drilling operations
Solution Approach 2:
The system transitions from static slide drilling to dynamic oscillating slide drilling. The top drive system continuously adjusts rotational oscillations to maintain optimal downhole toolface orientation while creating dynamic motion that reduces friction. This dynamic approach allows the drill string to oscillate through a controlled rotational range, preventing sticking while maintaining effective weight-on-bit
2Productivity
If rotational oscillations are imparted to the drill string to increase weight-on-bit, then the rate of penetration improves, but the downhole toolface orientation may become unstable
Solution Approach 1:
The system employs feedback control by continuously monitoring downhole toolface orientation through measurement-while-drilling tools and adjusting the rotational oscillations in real-time. The top drive system receives feedback on toolface orientation and modifies the amplitude and frequency of oscillations to maintain optimal orientation while maximizing weight-on-bit transfer to the drill bit
Solution Approach 2:
The system dynamically changes operational parameters including oscillation amplitude, frequency, and rotational direction to maintain stable toolface orientation. By adjusting these parameters in response to downhole conditions, the system optimizes weight-on-bit transfer while preventing toolface instability that could compromise wellbore trajectory
Data Source
AI summary
Apparatus and operational methods thereof, including a top drive, a rotation sensor, and a processing device. The top drive connects with an upper end of a drill string. The rotation sensor facilitates rotational distance measurements indicative of rotational distance achieved by the top drive. The processing device causes the top drive to impart rotational oscillations alternatingly in opposing directions to the upper end of the drill string while maintaining a downhole toolface orientation during a slide drilling operation, such that each rotational oscillation rotates the upper end of the drill string through a base rotational distance. The processing device also causes the top drive to change the downhole toolface orientation by an offset rotational distance by adding the offset rotational distance and an overshoot rotational distance to the base rotational distance of an instance of the rotational oscillations.