Halliburton Energy Services, Inc.

Sdg LLC

Chevron U.s.a. Inc.

Welldynamics, B.v.

Daniel David Gleitman

M Vikram Rao

Chen-Kang David Chen

Roger Lynn Schultz

Paul F Rodney

Colin Walker

Roger Boulton

Thomas M Gaynor

Travis Wayne Cavender

James H Dudley

Michael Linley Fripp

B Raghava Reddy

Christopher Michael Jones

Larry Steven Eoff

Jimmie Dean Weaver, Jr

Neal Gregory Skinner

Lance Everett Brothers

Frank Zamora

William M Moeny

Anthony V Palmer

John Ransford Hardin, Jr

James B Terry

Beegamudre N Murali

John R Hardin

Denise Berryhill

Anne M Culotta

John Michael Wilson

Glenda Wylie

Russell M Fitsgerald

Stephen Michael Greci

Michael Thomas Pelletier

William Walter Shumway

Harry D Smith, Jr

Gang Li

Ronald L Spross

Jerome Allen Truax

Michael Dewayne Finke

Robert Lee Pipkin

Clive D Menezes

Boguslaw Wiecek

James Randolph Lovorn

Ronald Johannes Dirksen

Derrick Winston Lewis

Michael John Strachan

David Crawshay

Chenkang David Chen

Saad Saeed

Haoyue Zhang

Harry Davis Smith, Jr

Jimmy R Coe

John W Gibson

Kristy Bell

Sharon Rector

Florin Anghelescu

Vikram M Rao

Li Gang

A screen assembly for wellbore production wherein a base pipe is wrapped with a screen constructed one or more cables formed from a plurality of non-metallic fibers bonded to one another with a metal binder. The non-metallic fibers may be basalt fibers or another ceramic material. The metal binder forms a metal matrix that has a first diameter about a primary cable axis, with the metal matrix securing the non-metallic fibers so that they have a second diameter about the primary cable axis, where the second diameter is larger than the first diameter, minimizing exposure of the metal matrix to wellbore fluids.

Metal-matrix downhole sand screens

An apparatus, that is part of a drill string for drilling a wellbore in a subsurface formation, comprises a drill bit that includes at least one electrode coupled to a power source, the at least one electrode to periodically emit an electrical discharge based on electrical pulses received from the power source; and a first port to output a first type of drilling fluid having a different composition than a second type of drilling fluid to flow downhole for removal of cuttings, wherein the electrical discharge is to be transmitted through the first type of drilling fluid and through a rock of the subsurface formation.

Pulsed power drilling with multiple selective drilling fluids

An apparatus comprises an electrode assembly positioned at a bottom end of a pulse power drill string to be positioned in a borehole formed in a subsurface formation. The electrode assembly comprises multiple electrodes, wherein at least a subset of the multiple electrodes is to periodically emit a pulse of an electrical discharge into the subsurface formation to drill the borehole. The electrode assembly comprises a controller configured to alter a direction of drilling of the borehole based on selection of the subset from the multiple electrodes, wherein an effective attribute of at least one electrode of the multiple electrodes is different than the effective attribute of other electrodes of the multiple electrodes, wherein the effective attribute comprises at least one of a shape and a size.

Selective electrode usage for directional pulse power drilling

A method comprises measuring pressures at a number of locations along a drill pipe of a drill string positioned in a wellbore, using a number of pressure sensors that are positioned on or within the drill pipe at different depths of the wellbore. The method includes determining a first pressure gradient between measured pressures measured by a first pair of pressure sensors of the number of pressure sensors and determining a second pressure gradient between measured pressures measured by a second pair of pressure sensors of the number of pressure sensors. The method includes determining a pressure gradient change based on a difference between the first pressure gradient and the second pressure gradient; and identifying that a downhole condition has occurred based, at least in part, on pressure gradient change.

Multiple distributed pressure measurements

Methods, computer programs, and systems for detecting at least one downhole condition are disclosed. Pressures are measured at a plurality of locations along the drillstring. The drillstring includes a drillpipe. At least one of the pressures is measured along the drillpipe. At least one downhole condition is detected based, at least in part, on at least one measured pressure.

A disclosed pulsed-power drilling system may include a controller that receives and analyzes feedback from downhole components reflecting changing conditions or performance measurements associated with a pulsed drilling operation to determine that an operating parameter of the drilling operation should be modified. The controller may output a control signal to cause an adjustment of a configurable downhole component, such as mechanical, electrical, or hydraulic component that affects the operating parameter, while the drill bit remains in the wellbore. The controller may adjust a segmented transformer of a pulse-generating circuit, changing the number of primary winding switches that are fired, or the timing of the firing of the switches, to modify characteristics of the generated pulses. Adjusting a downhole component may affect the drilling rate, the drilling direction, the flow of drilling fluid, a pulse rise time, a pulse repetition rate, or a rate of penetration for the drilling operation.

Downhole reconfiguration of pulsed-power drilling system components during pulsed drilling operations

A method of testing mechanical properties of an earth formation can include disposing a probe in a wellbore, impacting the probe against a wall of the wellbore, and measuring a parameter related to at least one of a displacement, displacement rate, strain, and strain rate, of at least one of the probe and the formation. Another method can include disposing a probe and a known material in a wellbore, and after the disposing, penetrating the known material with the probe. Another method can include disposing a probe in a wellbore, measuring a displacement of the probe into a wall of the wellbore while measuring a load applied to the probe, and applying fluid pressure to the formation via the probe.

In-situ geomechanical testing

Systems and methods for downhole measurement and communications are disclosed. The system includes a communications medium, at least partially disposed in a drillpipe, a processor coupled to the communications medium, at least two sensor modules coupled to the communications medium, where at least one of the sensor modules is along a drillpipe, and at least one communications coupler to couple at least one sensor module to the communications medium.

Multiple distributed sensors along a drillstring

A method for modifying a return fluid in a wellbore comprising disposing at least one valve along a drill pipe section of a drill string in the wellbore. At least one parameter of interest is determined at at least one location along the wellbore. At least one valve is controllably actuated to discharge at least a portion of at least one fluid from inside the drill string to an annulus in the wellbore to modify a local property of the return fluid in the annulus based at least in part on the measured parameter of interest.

Apparatus and method for well operations

The subject matter of this specification can be embodied in, among other things, a wearable computer device positionable on a human body. The wearable computer device is configured to receive sensor information from a collection of sensors that includes a first sensor and a second sensor, the first sensor attached to the human wearable device and the second sensor connected to the human wearable device, the sensor information describing operational attributes of the oil and gas drilling or production operations that either implements a hydrocarbon recovery process or a hydrocarbon recovery machine at a time of obtaining the sensor information, identify baseline sensor information describing operational attributes during normal operation of either the hydrocarbon recovery process or the hydrocarbon recovery machine, compare the sensor information and the baseline sensor information, and provide a notification indicating an operational condition of the oil and gas drilling or production operation.

Monitoring hydrocarbon recovery operations using wearable computer machines

A well system and associated method can include an acoustic generator which can be used to excite a formation with acoustic waves transmitted from the acoustic generator. Another well system and associated method can include an acoustic generator which can transmit acoustic waves into cement surrounding a casing. Another well system and associated method can include an acoustic generator which can be used to transmit acoustic waves into an annulus surrounding a well screen during or after a gravel packing operation. Another well system and associated method can include an acoustic generator which can be connected in a drill string in close proximity to a drill bit, with the acoustic generator transmitting acoustic waves into a formation ahead of the bit.

Acoustic generator and associated methods and well systems

Growing community of inventors

Houston, TX, United States of America

Daniel David Gleitman