Weatherford Technology Holdings, LLC

Precision Energy Services, Inc.

Mauldin, Charles, L.

Bartel, Roger, P.

Berns, Richard

Charles Lee Mauldin

Roger P Bartel

Richard E Berns

Liam A Lines

Barry Vincent Schneider

Mark Adrian Smith

Daniel Sullivan

Michael Louis Larronde

Steven Reid Farley

Robert Anthony Aiello

Curtis Alan Cheatham

Jacob Hill

Roger Bartel

Curtis Cheatham

Barry Schneider

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 method and apparatus for communicating incremental depth and/or other useful data of a downhole tool. The incremental depth and/or other useful data of the downhole tool being communicated by measuring at least one change in the downhole system, detecting the change downhole, and subsequently determining the incremental depth and/or other useful data of the downhole tool.

Method and apparatus for communicating incremental depth and/or other useful data of a downhole tool

Downhole drilling vibration analysis uses angular and linear motion data on a drilling assembly. During drilling operations, pairs of accelerometers measure the angular and linear motion of the drilling assembly. Processing circuitry is operatively coupled to the accelerometer pairs and is configured to determine type and severity of vibrations occurring during drilling based on the angular and linear motion data. Drilling operations can then be modified to overcome or mitigate the detrimental vibrations.

Analysis of drillstring dynamics using angular and linear motion data from multiple accelerometer pairs

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

Disclosed herein is a system for steering the direction of a borehole advanced by cutting action of a rotary drill bit by periodically varying action of a drill bit while continuously rotating a drill string to which the drill bit is operationally attached. The steering system can include a bit perturbation device cooperating with a bent housing subsection and operationally connected to the drill string and to the drill bit. Drill bit action can be varied by periodically varying the rotation speed and/or rate of penetration of the drill bit. Periodic drill bit action results in preferential cutting of material from a predetermined arc of the borehole wall which, in turn, results in borehole deviation. Action of the drill bit can be varied independently of the rotation rate of the drill string.

Directional drilling control using periodic perturbation of the drill bit

A tool driver activates a telemetry tool when a predetermined threshold of accelerometer data measured by an accelerometer. The threshold preferably corresponds to an acceleration level expected while drilling mud is pumped at a slow pump rate through the well's drill pipe. When a fluid influx occurs during drilling, the well is shut-in, and the tool driver turns off the telemetry tool. The drill pipe and casing pressures of the shut-in well are obtained. Then, drilling mud having a first weight is pumped at a slow mud pump rate. Because the tool driver is set to activate the telemetry tool in response to accelerometer data at the slow pump rate, the telemetry tool begins sending downhole pressure data to the surface. In this way, rig operations can change the mud weight and adjust the choke line during the kill operation based on an analysis of the downhole pressure data obtained.

System and method for obtaining and using downhole data during well control operations

Downhole drilling vibration analysis uses acceleration data measured in three orthogonal axes downhole while drilling to determine whether drilling assembly's efficiency has fallen to a point where the assembly needs to be pulled. In real or near real time, a downhole tool calculates impulse in at least one direction using the measured acceleration data over an acquisition period and determines whether the calculated impulse exceeds a predetermined acceleration threshold for the acquisition period. If the impulse exceeds the threshold, the tool pulses the impulse data to the surface where the calculated impulse is correlated to efficiency of the assembly as the drillstring is used to drill in real time. Based on the correlation, operators can determine whether to pull the assembly if excessive impulse occurs continuously over a predetermined penetration depth.

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Spring, TX, United States of America

Charles Lee Mauldin