Baker Hughes Corporation

Baker Hughes, a Ge Compnay, LLC

Baker Hughes Oilfield Operations LLC

Thorsten Regener

Ingo Roders

Christian Fulda

Harald Grimmer

Carsten Hohl

Gaute Grindhaug

Erik Bartscherer

Witali Huber

Gunnar Michaelis

Dorothea Marion Fischer

Matthias Wauer

Volker Krueger

Volker Peters

Andreas Peter

Matthew J Krueger

Heiko Eggers

Morten Eidem

Jonathan Mackey Hanson

Matthias Gatzen

Henning Melles

Fabian Mau

Markus Hempel

Russell Kurtis Fleetwood

Sascha Schwartze

Carl C Clemmensen

Kjetil Holden

Frank Johnsen

Freddy Seterdal

Eli William Adetola

Jannik Paul Hartmann

Trond R Skar

Tore Sorheim

Markus Walterskoetter

Kjell Magne Gronaas

Rick Frey

An apparatus for determining a location of an inner string in an outer string includes an axis parallel to a longitudinal axis of the inner string, and a tagging assembly disposed at a tagging location in the outer string, the outer string configured to be deployed into a borehole in a subterranean region, the inner string configured to be advanced through the outer string. The tagging assembly includes a stop component configured to obstruct axial movement of the inner string through the outer string at the tagging location, the stop component configured to be displaced in response to an axial force applied to the stop component by the inner string, to permit the inner string to advance axially beyond the tagging assembly.

Tagging assembly including a sacrificial stop component

A stator for a downhole motor configured for use in a downhole environment. includes an inner tubular member formed from a first metallic material having an outer surface and a helically lobed inner surface, and an outer tubular member comprising a second metallic material that is different from the first metallic material. The inner tubular member is connected to the outer tubular member by compressive force passing from the outer tubular member through the inner tubular member to a rigid mandrel removably disposed within the inner tubular member. The inner tubular member and the outer tubular member form the stator of the downhole motor.

Method of forming stators for downhole motors

A method of making a stator includes positioning an inner tubular member having an inner surface within an outer tubular member, installing a rigid mandrel within the inner tubular member, and applying a compressive force to at least one of the inner tubular member and the outer tubular member.

Systems and methods to perform a downhole operations in a borehole comprising moving, using surface equipment, an inner structure and an outer structure within the borehole, the outer structure equipped with an interaction device and the inner structure configured to be moved relative to the outer structure in a direction parallel to the borehole by the surface equipment, transmitting, by a transmitter, a downlink instruction to the inner structure, and performing an interaction routine with the interaction device in response to the downlink instruction, wherein the interaction routine comprises an interaction at least partially outside of the outer structure to perform the downhole operation.

Inner and outer downhole structures having downlink activation

Methods and systems to initiate downhole operations in a borehole include deploying a first structure at least partially in the borehole, moving a second structure at least partially along the first structure, wherein at least one of the first structure and the second structure is equipped with a sensor and the other of the first and second structure is equipped with a marker detectable by the sensor, detecting a critical event that is related to an interaction of the sensor and the marker, measuring a time-since-critical event, determining a time delay based on the time-since-critical event, transmitting, with a telemetry system, data from the earth's subsurface to the earth's surface indicating that the critical event has been detected, and initiating a downhole operation by using the determined time delay.

Methods and systems for detecting relative positions of downhole elements in downhole operations

Backflow prevention assemblies and methods for downhole systems having outer strings and inner strings include a housing defining a cavity and being part of the outer string, a flow tube disposed between the inner string and the outer string movable axially within the outer string, and a backflow prevention structure having a flapper and a seal seat, the flapper biased toward a closed position and maintained in an open position by the flow tube. The flapper is housed within the cavity when in the open position and the flapper and seal seat form a fluid seal to prevent fluid flow into or through the flow tube when in the closed position. When the flow tube is moved from a first position that maintains the flapper in the open position to a second position, the backflow prevention structure operates to close the flapper and seal the backflow prevention structure.

Backflow prevention assembly for downhole operations

An annularly shaped modular debris barrier can be mounted to an internal or an external member that are spaced apart to define an annular gap that could collect debris. The modules rotationally lock. Modules have circumferential segments that can be initially spaced apart to promote flexing that can occur when there is relative axial movement between the structures that define the annular gap. The gaps between segments are circumferentially offset as between adjacent segments to create a labyrinth through which the fluid can move in opposed direction while at the same time causing the debris to be retained. The segments stay in a flexed condition to exert a contract stress on the free ends thereof that touch the adjacent structure.

Modular annular debris barrier with rotationally locked segments

A method and apparatus for drilling a wellbore is disclosed. The wellbore is drilled with a drill string that includes a bypass device having a fluid passage therethrough by supplying a fluid through the bypass device at a first flow rate, wherein the fluid circulates to a surface location via an annulus between the drill string and the wellbore. The flow rate of the fluid is altered to a second flow rate. A time period is defined and a mechanical motion of the bypass device is initiated. A parameter related to the mechanical motion of the bypass device and a parameter related to flow rate are detected. The bypass device is activated to divert a portion of the fluid to the annulus when the parameter related to mechanical motion is detected and the parameter related to flow rate is present during the defined time period.

Drilling apparatus including a fluid bypass device and methods of using same

In one aspect, the disclosure provides a method of drilling a wellbore, which method, in one embodiment, includes the features of drilling the wellbore with a drill string that includes a bypass device having a fluid passage therethrough by supplying a fluid through the bypass device, wherein the drilling fluid circulates to the surface via an annulus between the drill string and the wellbore; defining a time period (locking time); initiating a selected drilling parameter; detecting downhole the selected drilling parameter and one of the second flow rate and a differential pressure; and activating the bypass device when the selected drilling parameter and one of the second flow rate and the differential pressure are present during the defined time period to divert a portion of the drilling fluid from the bypass device to the annuls. In one aspect, the selected drilling parameter is rotation of a member associated with the bypass device.

A method of forming a wellbore is disclosed. An inner string and an outer string are conveyed downhole. The inner string is attached to the outer string at a first location and the wellbore is formed. The inner stringy is attached to the outer string at a second location us hole of the first location and an annulus between the outer string and the wellbore is cemented without retrieving the inner string from the wellbore.

Apparatus and method for drilling a wellbore, setting a liner and cementing the wellbore during a single trip

The present invention provides methods of forming mud motors. In one method, rollers are urgingly stroked against a tubular member having a mandrel therein that has an outer profile which is the inverse of the desired profile of the stator. In another method, rollers are urged and rotated radially on the tubular member with the mandrel disposed in the tubular member. In yet another method, dies are pressed against the tubular member having a mandrel with a desired outer profile. In another method, a molten metal is deposited over a mandrel with an outer lobed surface that is substantially the inverse of the desired inner profile of the stator housing. The mandrel is then removed, leaving a metallic longitudinal member having an inner profile defined by the outer profile of the mandrel. In each of these methods, the inner surface of the resulting member has the profile defined by the outer profile of the mandrel. The inner surface of the resulting member then may be coated or lined with a suitable material for the stator. A suitable rotor is then disposed in the stator to form the drilling motor.

Methods of making mud motors

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Wienhausen, Germany

Thorsten Regener