Weatherford Technology Holdings, LLC

Weatherford/lamb, Inc.

Thomas Koithan

David M. Haugen

Graham Ruark

John W. Newman

David Shahin

Thomas H Koithan

David Michael Haugen

Thomas M Redlinger

Andrew Antoine

Scott McIntire

Graham Myles Ruark

Christopher M Vreeland

John Newman

Jose D Brana

Wesley Don Heiskell

Sayamik N Ameen

Wes Heiskell

Scott Mcintire

Lizabeth J Ly

Andrew V Ilin

Levi C Banuta

John W Newman

Sayamik Ameen

Andrew Ilin

A pressure control assembly can include an outer housing and a rotating control device including a bearing assembly with a rotatable inner barrel, a pressure sensor and one or more magnetic field generators, and at least two seal elements configured to seal between the inner barrel and a tubular positioned in the pressure control assembly. A magnetic field detector secured to the outer housing is configured to receive signals from the magnetic field generators, the signals being indicative of outputs of the pressure sensor. A method can include securing a magnetic field detector to an outer housing, installing the rotating control device in the outer housing, the rotating control device comprising a rotatable inner barrel, a pressure sensor and multiple magnetic field generators, and transmitting signals indicative of outputs of the pressure sensor from the magnetic field generators to the magnetic field detector.

Monitoring operation of a rotating control device

Control of a drilling system drilling a wellbore is improved using a hydraulic model corrected for pressure losses. A surface backpressure of the outlet and a standpipe pressure of the inlet are measured with sensors in the system. An estimate of the standpipe pressure is calculated based integrating from the measured surface backpressure back to the inlet in the hydraulics model. The pressure loss increment in the hydraulics model is calculated based on a difference between the measured and estimated standpipe pressures. Meanwhile, a parameter in the drilling system is monitored during drilling so the parameter can be adjusted at least partially based on the hydraulics model corrected for the pressure loss.

Drilling system and method using calibrated pressure losses

A system and method are used in drilling a borehole in a formation. A trip to move a drillstring in the borehole is identified, where the trip is expected to produce a piston effect that changes a downhole pressure of the fluid in the borehole. A peak speed to move the drillstring in the borehole is calculated for the trip, and adjustments to a surface backpressure of the drilling system is calculated for the trip at the calculated peak speed to keep the downhole pressure within a tolerance of the formation. The drillstring is moved in the trip according to the calculated peak speed, and the downhole pressure change produced by the piston effect is counteracted by automatically adjusting the surface backpressure according to the calculated adjustments.

Automatic compensation for surge and swab during pipe movement in managed pressure drilling operation

An apparatus for identifying a tool joint connection is disclosed comprising a scanning system configured to scan an exterior of a drill string, at least one distance measuring sensor mounted to a movable platform and a computer connected to the scanning system and the at least one distance measuring sensor, wherein the computer is configured to receive data from a scanning of the exterior of the drill string and compare the data from the scanning to a reference to determine a presence of the tool joint connection.

Tool joint finding apparatus and method

A mud motor for use in a wellbore includes: a stator; a rotor, the stator and rotor operable to rotate the rotor in response to fluid pumped between the rotor and the stator; and a lock. The lock is operable to: rotationally couple the rotor to the stator in a locked position, receive an instruction signal from the surface, release the rotor in an unlocked position, and actuate from the locked position to the unlocked position in response to receiving the instruction signal.

Signal operated drilling tools for milling, drilling, and/or fishing operations

Signal operated tools for milling, drilling, and/or fishing operations

A method and apparatus for connecting threaded members while ensuring that a proper connection is made. In one embodiment, the applied torque and/or rotation are measured at regular intervals throughout a pipe connection makeup. When a shoulder contact is detected, a predetermined torque value and/or rotation value is added to the measured torque and/or rotation values, respectively, at shoulder contact and rotation continued until this calculated value(s) is reached.

Methods and apparatus for applying torque and rotation to connections

The present invention generally provides a method for remotely controlling and/or monitoring at least one parameter of well bore equipment. In one aspect, a method for remotely controlling and/or monitoring at least one parameter of well bore equipment is provided, including: collecting data corresponding to the at least one parameter by a sensor module monitoring the at least one parameter of the well bore equipment; transmitting the collected data to a remote control/monitoring unit via a communication link; analyzing the collected data to determine if the parameter is within predefined limits; if the parameter is not within predefined limits, then transmitting control data from the control/monitoring unit to the well bore equipment for modifying the operation of the well operation equipment so that the parameter will conform to the predefined limits or stopping operation of the wellbore equipment.

Method and apparatus for controlling wellbore equipment

The present invention generally provides a method for remotely controlling and/or monitoring at least one parameter of well bore equipment. In one aspect, the invention includes a method comprising the steps collecting data corresponding to the parameter with a sensor module; transmitting the collected data to an on-site universal data acquisition and control system; transmitting the data from the universal data acquisition and control system to a remote control/monitoring unit via a communication link; and transmitting control data from the control/monitoring unit back to at least the universal data acquisition and control system for modifying the operation of the well operation equipment.

Growing community of inventors

Houston, TX, United States of America

Thomas H Koithan