Smith International, Inc.

Weatherford/lamb, Inc.

Weatherford Technology Holdings, LLC

Tommy Laird

Navish Makkar

Gordon Whipple

Wei Tang

Gail Nelson

Wei Xu

Sujian Huang

Simon John Harrall

Albert C Odell, Ii

David J Brunnert

Frederick Thomas Tilton

Thomas M Redlinger

Michael J Moody

Andrew Antoine

Christopher M Vreeland

Michael Moody

Albert C Odell

Richard C Davis

A method for designing a secondary cutting structure for use in a bottom hole assembly, the method including defining initial design parameters for the secondary cutting structure and analyzing forces acting on the secondary cutting structure. Additionally, the method includes modifying at least one design element of the secondary cutting structure and simulating an effect of the modifying on both the secondary cutting structure and a primary cutting structure to determine if an improved condition is met. Also, a method for designing a drilling tool assembly, the method including defining initial drilling tool assembly design parameters including a primary cutting structure and a secondary cutting structure, and simulating a dynamic response of the drilling tool assembly. Additionally, the method includes adjusting at least one design element of the secondary cutting structure based on the dynamic response of the drilling tool assembly, determining if the adjusted design element improved a condition of the drilling, and repeating the simulating and adjusting until the condition is optimized.

Methods for designing secondary cutting structures for a bottom hole assembly

Embodiments of the present invention generally relate to extendable cutting tools for use in a wellbore. In one embodiment, a tool for use in a wellbore includes a tubular body having a bore therethrough, an opening through a wall thereof, and a connector at each longitudinal end thereof; and an arm. The arm is pivotally connected to a first piston and rotationally coupled to the body, is disposed in the opening in a retracted position, and is movable to an extended position where an outer surface of the arm extends outward past an outer surface of the body. The tool further includes the first piston. The first piston is disposed in the body bore, has a bore therethrough, and is operable to move the arm from the retracted position to the extended position in response to fluid pressure in the piston bore exceeding fluid pressure in the opening. The tool further includes a lock operable to retain the first piston in the retracted position; and a second piston operably coupled to the lock.

Extendable cutting tools for use in a wellbore

A method for forming a borehole enlargement tool that includes providing a steel body structure, forming at least one rib structure from a matrix material and abrasive particles, affixing the at least one rib structure to the body structure, and affixing the steel body structure to an elongated tubular body is disclosed.

Expandable earth boring apparatus using impregnated and matrix materials for enlarging a borehole

A downhole tool including a tubular body having an upper connection and a lower connection and an axial borehole therethrough, wherein the upper and lower connections are configured to connect to a drilling assembly, at least one expandable component coupled to the tubular body and configured to selectively extend radially therefrom, and an actuation assembly configured to selectively actuate, deactuate, and reactuate the at least one component. A method of selectively actuating a downhole tool, wherein the downhole tool comprises a tubular body with an axial borehole therethrough and at least one component, the method including circulating a drilling fluid in the axial borehole of the downhole tool, actuating the at least one component, deactuating the at least one component, and reactuating the at least one component. An actuation assembly including a mandrel having an actuation chamber port, at least one drop device, a piston disposed within the mandrel and configured to move to open the actuation chamber port, at least one dart, a sleeve disposed within the mandrel and configured to move to close the actuation chamber port; and at least one biasing member configured to exert a force on the sleeve in an upstream direction.

Downhole tool deactivation and re-activation

A tool for enlarging a borehole that includes an elongated tubular body; at least one movable arm affixed to the tubular body, the at least one movable arm comprising an outer surface formed of at least one of a matrix material and an abrasive material; and at least one actuating member for expanding at least one movable arm from the collapsed state to an expanded state is disclosed.

A secondary cutting structure for sure in a drilling assembly, the secondary cutting structure including a tubular body and a block, extendable from the tubular body, the block including a first arrangement of cutting elements disposed on a first blade and a second arrangement of cutting elements disposed on a second blade, wherein the second arrangement is a modified redundant arrangement. Also, a secondary cutting structure for use in a drilling assembly, the secondary cutting structure including a leading blade disposed on a first block and a trailing blade disposed on the first block adjacent the leading blade. Additionally, the secondary cutting structure includes a unique blade disposed on a second block, wherein a gage portion of at least one of the blades has a length between 30% and 45% of a total blade length.

Placement of cutting elements on secondary cutting structures of drilling tool assemblies

An expandable underreamer apparatus disposed on a distal end of a drillstring and configured to drill a formation includes a substantially tubular main body adjacent a cutting head, the main body providing at least one axial recess configured to receive an arm assembly, and the arm assembly configured to translate between a retracted position and an extended position. The apparatus further includes a plurality of cutting elements disposed on the arm assembly, and a plurality of wear indicators imbedded in at least one arm assembly and positioned behind the cutting elements with respect to a direction of rotation of the arm assembly, wherein the wear indicators are configured to provide an increased torque to the drillstring upon contacting the formation.

Growing community of inventors

Cypress, TX, United States of America

Tommy Laird