Halliburton Energy Services, Inc.

Ricardo Ortiz

Kristopher V Sherrill

Michael Dewayne Finke

Minh Dang Nguyen

Batakrishna Mandal

Mark Anthony Sitka

Paul Andrew Cooper

Hasib Uddin

Daniel Flores

Kristopher V Sherril

A bottom hole assembly ('BHA') includes a driveshaft including a bore through which the drilling fluid is flowable. The BHA also includes a bearing assembly configured to rotatably support the driveshaft that includes a radial bearing with an internal radial gap; an annular flow restrictor with an inner sleeve and an outer sleeve separated by a restrictor clearance; and a bypass fluid flow path open to the bore and extending through the radial gap and the restrictor clearance such that at least some drilling fluid is diverted from the bore into the bypass fluid flow path. The restrictor clearance is sized to restrict flow of the drilling fluid diverted through the bypass fluid flow path to control a pressure of the drilling fluid in the driveshaft. The outer sleeve is dynamically radially supported such that a radial load absorbed by the annular flow restrictor is below a selected threshold.

Drilling system with mud motor and annular flow restrictor

A downhole tool includes a window cap located in a cover that is positioned between an electromagnetic radiation detector in the downhole tool and a geological formation into which a borehole is formed and where the downhole tool is to be positioned. The electromagnetic radiation detector is to detect an electromagnetic radiation from the geological formation. The downhole tool includes a window core positioned behind the window cap relative to an external environment of the downhole tool, wherein the window core is positioned between the window cap and the electromagnetic radiation detector.

Window core for gamma ray detection in a downhole tool

Bendable fastener

Fastener with anti-rotation device

A downhole sensor tool includes a sensor outsert coupled into an exterior pocket of the tool body. The sensor outsert is a pressure vessel with an exterior electrical connector coupled to the interior sensor. The sensor outsert contains a sensor, and is pressure-sealed about the sensor. The outsert includes an electrical connector coupled to the sensor. The electrical connector maintains the pressure seal of the outsert. The electrical connector may be a hermetic connector. The electrical connector can be coupled to an electrical connector or a hermetic connector of the tool body while maintaining the sealing of the pressure vessel.

Downhole sensor tool with a sealed sensor outsert

A method of modulating information on pressure fluctuations transmitted via a tubular string can include applying pressure to a piston, thereby axially displacing the piston, axially displacing and rotating an intermediate sleeve in response to the piston displacement, rotating an output member in response to the axial displacement and rotation of the intermediate sleeve, and rotating a variable flow restrictor rotor relative to a stator, the rotor being connected to the output member. A mud pulser can include a variable flow restrictor, and an actuator which operates the flow restrictor and modulates information on pressure fluctuations produced by the flow restrictor, the actuator including a piston which displaces axially in response to a pressure differential, an intermediate sleeve which is both rotated and displaced axially by the piston, and an output member which is rotated by both rotation and axial displacement of the intermediate sleeve.

Mud pulser with high speed, low power input hydraulic actuator

Apparatus, systems, and methods may operate to emit acoustic pulses into a drilling fluid in a well bore, using a first acoustic transducer in a downhole tool, and detecting the acoustic pulses after reflection from the wall of the well bore, using a second acoustic transducer in the downhole tool. The faces of the first and second acoustic transducers are non-parallel. Further activities include emitting additional acoustic pulses into the drilling fluid using the second acoustic transducer, and detecting them using the second acoustic transducer. The acoustic velocity of the drilling fluid can be determined based on respective travel times. Additional apparatus, systems, and methods are described.

Acoustic velocity measurements using tilted transducers

A downhole measurement apparatus includes a tool body supporting a logging tool. The logging tool includes a detector outsert coupled into and exposed through an exterior pocket of the tool body to position the outer surface of the outsert adjacent or in close proximity to the outer diameter of the tool body. A stabilizer or off-center stabilizer may be provided to further deflect the outsert portion of the logging tool toward an earth formation to increase detector proximity to the formation. Radial and axial distances can be calibrated and maintained across multiple different tool collars.

Downhole sensor tool for logging measurements

A downhole measurement apparatus includes a tool body supporting a logging tool. The logging tool includes a detector outsert coupled into and exposed through an exterior pocket of the tool body to position the outer surface of the outsert adjacent or in close proximity to the outer diameter of the tool body. A stabilizer or off-center stabilizer may be provided to further deflect the outsert portion of the logging tool toward an earth formation to increase detector proximity to the formation. The axial distance between the detector and a nuclear source can be calibrated using configurations of the nuclear source holder and the outsert. Retention mechanisms for the source holder and the outsert further enhance proximity and calibration.

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Houston, TX, United States of America

Ricardo Ortiz