Halliburton Energy Services, Inc.

Richard Thomas Hay

Burkay Donderici

Joe Eli Hess

Robello Samuel

Clive D Menezes

Rodney Alan Schnell

Mac Upshall

Dean Lee

Kyler Tebbutt

Tracy Lorne Grills

Barry Gerard Ryan

Wei Zhang

Neelesh V Deolalikar

Daniel Winslow

Kennedy John Kirkhope

Christopher A Golla

John Ransford Hardin, Jr

Colin Walker

John Gerard Evans

Edward James Cargill

Charles M Reid

Gary Lorne Donison

Hernando Jerez

Gary M Crase

Nestor Humberto Gil

Nesto Humberto Gil

John G Evans

Hernando Q Jerez

Paul F Rodney

Evan Lloyd Davies

Jody Ray McGlothen

Laurier E Comeau

Boguslaw Wiecek

Mark Anthony Sitka

Randal Thomas Beste

James H Dudley

Ronald G Earles

Larry DeLynn Chambers

Imran Sharif Vehra

John Kenneth Snyder

Jonathan Peter Zacharko

Umut Zalluhoglu

Michael W Holcombe

Ravi P Nanayakkara

Fraser A Wheeler

Jeffrey Bowden Lasater

Michael John Strachan

Clint Paul Lozinsky

Victor Gawski

John R Hardin

Gary Dean Althoff

Ragi Lohidakshan Poyyara

Satish Rajagopalan

Ian Gillis

Daniel P Lupien

Sergei Sharonov

Krunal Kanubhai Mehta

Terrance Dean Maxwell

Bryan James Restau

David Yan Lap Wong

Richard D Bottos

Pete L Schiermeier

Gerald Edward Kent

Aixa Maria Rivera-Rios

Byron John Sand

David Lyle

Terence Allan Schroter

Keith E Holtzman

Sean Hinke

Raymond C Smith

Malcolm R Upshall

Christopher W Konschuh

Paul Roberts

Julio Garcia

Heiko Schmirgel

Arthur G Mansell

Mevis Juliana Tarazona Mercado

Paul Botterell

Nathan Strilchuk

Paul Rieder

Lisa Yung

Rohit Sankeshwari

Mac Upsahll

Jerry Lavelle Keen, Jr

Terence Schroter

Daniel M Winslow

Clint P Lozinsky

David Yan Wong

Jonathan P Zacharko

Daniel Lupien

Edward Cargill

Systems and methods for drilling a first borehole along a planned first path using a first bottom hole assembly (BHA) while drilling a second borehole using a second BHA along a second path having a defined spatial relationship to the first path. The method includes steps of measuring a distance and a direction of the first BHA relative to the second BHA, automatically adjusting the second path based in part on the measured distance and the measured direction so as to maintain the spatial relationship, and automatically steering the second BHA to follow the adjusted second path.

Automated wellbore ranging

Systems and methods for drilling a wellbore include delivering electrical energy to a downhole end of the wellbore. A tapered drill string, with larger drill pipes connected in an up-hole portion with a turbine and an electrical generator and a smaller drill pipes coupled in downhole portion may be used to deliver the electrical power. A turbine and generator may be sufficiently sized to harvest the necessary hydraulic energy and safely operated in a subterranean environment. A lower portion system carried by the downhole portion of the drill string is electrically coupled to the generator through the downhole portion of the drill string to utilize the electric power provided by the electrical generator.

Tapered string pulse power rock excavation system

Systems and methods for drilling a wellbore include delivering electrical energy to a downhole end of the wellbore. A tapered drill string, with larger drill pipes connected in an up-hole portion with a turbine and an electrical generator and a smaller drill pipes coupled in downhole portion may be used to deliver the electrical power. A turbine and generator may be sufficiently sized to harvest the necessary hydraulic energy and safely operated in a subterranean environment. An electrode carried by the downhole portion of the drill string is electrically coupled to the generator through the downhole portion of the drill string.

An extendable member diagnostic assembly determines performance of one or more components of a rotary steerable system. Based on the determined performance, an operation can be altered, such as a drilling operation. Performance may be based on measurements received from one or more sensors associated with components of the extendable member diagnostic assembly. For example, performance may be based on the time to transition a valve between states where the valve controls actuation of an extendable member, downhole temperature, downhole pressure or any other factors that affect performance of components that are used to perform the drilling operation. A controller receives the measurements from the one or more sensors and updates baseline parameters to determine an accurate performance. Using real time data to determine performance increases efficiency of an operation by eliminating unnecessary replacement of components and indicating that a downhole tool should be retrieved prior to failure.

Using solenoid characteristics for performance diagnostics on rotary steerable systems

A method for controlling a drilling trajectory of a wellbore includes receiving a target trajectory reference of a drill bit within a wellbore from a formation model. The method also includes receiving real-time formation evaluation measurements from at least one sensor positioned within the wellbore and computing a target trajectory set-point change based on the real-time formation evaluation measurements. Further, the method includes generating a target trajectory from the target trajectory reference and the target trajectory set-point change and steering the drill bit using the target trajectory.

Trajectory control for directional drilling using formation evaluation measurement feedback

A drilling system for drilling a wellbore that includes a drill string rotatable in a first direction. The system also includes a bottom hole assembly (BHA) that includes: a drill bit, a housing with a bore, a first fluid-driven motor in fluid communication with the bore and connected with and configured to rotate a portion of the BHA in a second direction opposite the first direction, a second fluid-driven motor in fluid communication with the bore and connected with and configured to rotate the drill bit, a valve in fluid communication with a vent including a flow path arranged to direct fluid away from any one or both of the fluid-driven motors, and a controller in communication with and configured to adjust a drilling parameter of the BHA by controlling the valve to adjust a flow rate of the fluid output from the valve into the vent.

System and method to control a dual motor rotary steerable tool

A system for and method of use with a downhole tool that includes a tubular with a fluid flow path therethrough for flowing a fluid and a housing coupleable to a downhole portion of the tubular. A fluid-driven motor assembly is included and has a drive shaft rotatable to output rotational drive forces. An electric generator is coupled to the drive shaft to convert the rotational drive forces into electrical power. There is also an electric motor electrically coupled to the electric generator to convert electrical output of the electric generator into a rotational drive force to control the downhole tool. A controller is electrically coupled to the electric motor and the electric generator to conduct electrical power output from the electric motor to the electric generator and dissipate excess energy produced by the electric motor to the fluid-driven motor assembly as hydraulic energy.

Systems and methods for recycling excess energy

A pipe in pipe electric heater assembly comprising a work string comprising an inner pipe and an outer pipe and a heater element, wherein the heater element is provided with power supplied by the inner pipe and the outer pipe acting at least as conductors and associated methods.

Pipe in pipe downhole electric heater

Control valves can allow for a steering assembly of a drill string. An exemplary control valve can include a first valve element including a first orifice, the first valve element being movable by actuation by a motor, and a second valve element including an orifice, wherein flow passing through the first valve element orifice passes through the second orifice and into a flow channel to be in fluid communication with a piston bore to exert pressure against a piston movable within the piston bore, the piston being coupled to a steering pad for applying force against the wellbore wall to steer a direction of the drill string. The first valve element is movable with respect to the second valve element to change flow through the first valve element orifice and the second valve element orifice to modify fluid pressure within the flow channel that is exerted against the piston.

Steering assembly control valve

A drilling system includes a roller cone drill bit having a roller cone and at least one antenna loop disposed in the roller cone for detecting magnetic or electromagnetic waves indicative of a target, a resistivity, or a boundary of the subterranean formation, man-made structure, or object. The drilling system may utilize the antenna loop to determine resistivity measurements of a subterranean formation through which the drill bit is being drilled. The location of the antenna in the roller cone may enable increased look-ahead and look-around measurements. In addition, the location of the antenna in the roller cone may facilitate anisotropic resistivity measurements to aid in steering the drill string into a desired portion of the subterranean formation.

Roller cone resistivity sensor

An example method for control of a drilling assembly includes receiving measurement data from at least one sensor coupled to an element of the drilling assembly positioned in a formation. An operating constraint for at least a portion of the drilling assembly may be determined based, at least in part, on a model of the formation and a set of offset data. A control signal may be generated to alter one or more drilling parameters of the drilling assembly based, at least in part, on the measurement data and the operating constraint. The control signal may be transmitted to a controllable element of the drilling assembly.

Closed-loop drilling parameter control

A drill bit analysis and optimization system for use in a wellbore is provided. The system includes a drill bit including a cutter, a sensor that collects a data signal on a surface of the drill bit proximate to the cutter, and a signal processor unit that receives the data signal from the sensor and receives the expected drilling properties from the data reservoir. The processor analyzes the data signal to detect a resistivity profile from the sensor through a formation and optimizes a drilling parameter by comparing actual drilling properties with expected drilling properties.

Systems and methods for drill bit and cutter optimization

Apparatus, systems, and methods may operate to transmit a data signal along a transmission line extending lengthwise along a drill string, the transmission line comprising an outer conductive path provided by a tubular wall of a drill pipe that extends along the drill string; and an internal conductive path extending along an interior passage that is bounded by a radially inner cylindrical surface of the drill pipe and along which drilling fluid is conveyed, the inner conductive path being substantially insulated from the outer conductive path. Additional apparatus, systems, and methods are described.

Data transmission in drilling operation environments

Systems and methods for visualizing data from radially-oriented look-ahead sensors coupled to a drill bit are disclosed herein. A system comprises a processor, a memory, and a data analysis module. The data analysis module is operable to receive formation information from each of a plurality of formation sensors coupled to a downhole drilling system, the formation information being associated with one or more properties of a formation at a depth in front of the downhole drilling system, receive angular information from one or more orientation sensors coupled to the downhole drilling system, the angular information being associated with the formation information, compile sensor data based on the formation information and the angular information, and generate a visualization based on the sensor data.

Visualization of look-ahead sensor data for wellbore drilling tools

A method and apparatus for ranging from ahead of a drill bit is described. The ranging apparatus includes a ranging probe with at least one sensor that may be deployed ahead of the drill bit. The ranging probe may be conveyed via a cable through the interior of a drill string. In an alternative embodiment, the ranging probe may be attached to a ram that is seated inside of the drill string and that may be extended and retracted. In such an embodiment, the ranging probe may be retrievable by cable. The ranging probe optionally includes collapsible arms that retract when the ranging probe is inside the drill string or drill bit and that extend when the ranging probe is deployed ahead of the drill bit. One or more ranging sensors may be coupled to the collapsible arms. Ranging measurements may be communicated to the surface using telemetry.

Method and apparatus for ranging to a nearby well from ahead of a drill bit

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Spring, TX, United States of America

Richard Thomas Hay