Weatherford Technology Holdings, LLC

Precision Energy Services, Inc.

Mauldin, Charles, L.

Bartel, Roger, P.

Berns, Richard

Richard E Berns

Charles Lee Mauldin

Roger P Bartel

Liam A Lines

Daniel Sullivan

Roger Bartel

Charles Maudlin

Angular position readings are obtained during rotation of an apparatus in a borehole, and angular rate readings are obtained over time of the rotation. The angular rate readings are adjusted based at least on the angular position readings. The angular position measurement does not require calibrated magnetometers or accelerometers to function. Additionally, a dynamic scale factor calculation for an angular rate gyroscope (ARG) allows the ARG to be used over a much wider operating range than without such a calculation. Finally, an integrated angular rate from the ARG calibrated for bias and scale factor fills in positional information between the magnetometers' zero crossings to deliver a high resolution hybrid angular position system capable of measuring precise angular position at high and irregular downhole rotation rates.

Control for rotary steerable system

Downhole drilling vibration analysis uses an angular rate sensor on a drilling assembly. During drilling operations, the sensor measures the angular rate of the drilling assembly. Processing circuitry is operatively coupled to the angular rate sensor and is configured to determine whether torsional type vibrations are occurring during drilling based on the angular rate data. Drilling operations can then be modified to overcome or mitigate the torsional type vibrations.

Analysis of drillstring dynamics using an angular rate sensor

A downhole drilling vibration analysis involves measuring orientation data in at least two orthogonal axes downhole while drilling with a drilling assembly. For example, two orthogonal magnetometers can be used. A toolface of the drilling assembly is determined using the measured sensor data, and velocity (RPM) values for the toolface for a plurality of revolutions of the drilling assembly are determined. From these determined values, a coefficient of variation for the toolface velocity (RPM) values for the revolutions of the drilling assembly is calculated. When a pattern in found in the toolface velocity (RPM) and/or the calculated coefficient of variations exceed one or more thresholds, the processing device determines that detrimental vibrations are occurring in the drilling assembly.

Analyzing toolface velocity to detect detrimental vibration during drilling

Growing community of inventors

Conroe, TX, United States of America

Richard E Berns