Schlumberger Technology Corporation

Isodrill, Inc.

Gyrodata, Inc.

Schlumberger Canada Limited

Stephen D Bonner

Brian Oliver Clark

Richard A Rosthal

Thomas D Barber

Dean M Homan

Dzevat Omeragic

Saad Bargach

Mark T Frey

David L Smith

Jacques A Jundt

Anthony Louis Collins

John F Hunka

Martin G Luling

Dhananjay Ramaswamy

Scott S Chesser

Kuo-Chiang Chen

James Patrick Massey

Raymond V Nold, Iii

Jon Brunetti

Madhusudhan Nagula

Gerald N Minerbo

Abdullah A Bagersh

Jon A Brunetti

Raymond V Nold

James P Massey

Robert C Smith

Tsili Wang

Borislav J Tchakarov

Eugene J Linyaev

Robert A Adolph

Jean-Michel Hache

Charles G Kibbe

Gary A Hazen

Jun Zhang

David T Oliver

Kuo Chiang Chen

Ricki Don Marshall

John Preston Rogers

Treston Greggory Davis

Christopher Hopkins

Jing Li

Dean M Horman

Robert Rudolph Kirby

Niina Nobuyoshi

Feng Zhou

Christian Stoller

Charles Kibbe

Ruvinda Gunawardana

Larry J Bernard

Guillaume Revellat

Raymond V Nold Iii

Raymond V Iii Nold

A gap sub uses a plurality of insulating members in conjunction with at least two metallic members to effect a mechanically and electrically robust configuration. The gap sub includes an upper end portion, a lower end portion, an outer sleeve, an inner sleeve, an insulating outer washer, an insulating inner washer, and an insulating spider. The insulating outer washer is configured to transfer a first axial load between the upper end portion and the outer sleeve. The insulating inner washer is configured to transfer a second axial load between the inner sleeve and the lower end portion. The insulating spider is configured to transfer a torsional load between outer sleeve and the inner sleeve. Because the insulating washers are utilized to transfer axial loads and the insulating spider is utilized to transfer torsional loads, each insulator may be manufactured so that the strongest axis of the material can be optimally and advantageously oriented to be coincident with the forces applied to each insulator, thereby making the gap sub more mechanically robust than a conventional insulated gap collar while permitting reliable and fast transmission of sensor data to the surface.

Data transmission system

A data transmission system for use with a drill string in a primary wellbore is disclosed. The data transmission system includes a toroidal antenna assembly. The toroidal antenna assembly is disposed around the drill string at a primary downhole location within the primary wellbore and configured to transmit a signal from a transmitter. The signal corresponds to sensor data. The toroidal antenna assembly includes a plurality of toroidal antennas, wherein each toroidal antenna is configured to transmit the same signal from the transmitter. Because a plurality of toroidal antennas are utilized to transmit the same signal, construction of the drill string can be more mechanically robust than a conventional insulated gap collar while permitting reliable and fast transmission of sensor data to the surface.

A dynamically controllable variable displacement axial piston pump is described. In an embodiment, the pump comprises a rotating cylinder with hydraulic pistons that contact the face of a swash plate. The angle of the swash plate can be controlled to thereby control the movement of the pistons, the displacement of the pump, and the power generated by the pump. The dynamically controllable variable displacement axial piston pump may be used in combination with a rotary steerable apparatus, including such an apparatus as described herein that uses hydraulic pistons to actuate the deflection of the bit, or in combination with other downhole tools and devices. When used down hole in a drill string with a drilling mud powered turbine, the dynamically controllable variable displacement pump limits and regulates the power provided to the tool over a wide range of drilling mud weights and flow rates.

Downhole power conversion and management using a dynamically variable displacement pump

The rotary steerable drilling tool and system described herein combines both point-the-bit and push-the-bit techniques to actively change the direction of the borehole trajectory. In this system, the deflection of the drill bit is limited to a single degree of freedom relative to a coordinate system that is fixed to and rotates with the rotary steerable drilling tool, resulting in a simplified attachment of the bit assembly and bias unit mechanics. Further, steering of the well is accomplished by dynamically controlling the spatial phase and amplitude of the coherent symmetrical bidirectional reciprocating deflections of the drill bit relative to a fixed terrestrial datum as the tool is rotating, simultaneously pointing and pushing the bit. Alternatively, when not being used to change the direction of the borehole trajectory, the rotary steerable drilling tool apparatus can be used to mitigate or abate the stick-slip tendencies of the drill string by dithering the bit using spatially variable asynchronous symmetrical bidirectional reciprocating deflections of the drill bit at frequencies that are different from the rotational frequency of the bottom hole assembly. When neither steering nor stick-slip abatement is active, the bit can be mechanically locked into the neutral position.

Downhole apparatus and method for torsional oscillation abatement

The rotary steerable drilling tool and system described herein combines both point-the-bit and push-the-bit techniques to actively change the direction of the borehole trajectory. In this system, the deflection of the drill bit is limited to a single degree of freedom relative to a coordinate system that is fixed to and rotates with the rotary steerable drilling tool, resulting in a simplified attachment of the bit assembly and bias unit mechanics. Further, steering of the well is accomplished by dynamically controlling the spatial phase and amplitude of the coherent symmetrical bidirectional reciprocating deflections of the drill bit relative to a fixed terrestrial datum as the tool is rotating, simultaneously pointing and pushing the bit. The amplitude and force of the bit deflections can be variably controlled during steering operations to dynamically adjust the instantaneous build rate as needed. When steering is not active, the bit can be mechanically locked into the neutral position.

Rotary steerable drilling tool

A valve for communication of a measurement while drilling system includes a first structure having a central portion and one or more elongate portions radially extending from the central portion, and a second structure having one or more portions which substantially bound a central orifice region and one or more elongate orifice regions radially extending from the central orifice region. At least one of the first structure and the second structure is configured to be rotated about a rotation axis to produce a relative rotation between the first structure and the second structure such that a flow path through which mud can flow varies as the at least one of the first structure and the second structure rotates about the rotation axis. The central portion has a maximum inscribed circle encircling the rotation axis and having a first radius and the central orifice region has a maximum inscribed circle encircling the rotation axis and having a second radius greater than the first radius.

Valve for communication of a measurement while drilling system

A drilling system for drilling a lateral borehole from a main borehole comprises a tubular conduit through which a fluid can be pumped, and a drilling assembly connected to the tubular conduit so as to receive fluid pumped therethrough. The drilling assembly comprises a power conversion unit, through which the fluid flows and which operates to provide a downhole power output; a drilling unit including a drilling apparatus powered by the output of the power conversion unit and operable to drill a lateral borehole into the formation surrounding the main borehole, and a liner unit for storing one or more liners for installation into the lateral borehole; and an anchor unit operable to anchor the drilling assembly in the main borehole when the drilling unit operates to drill the lateral borehole. A method of drilling a lateral borehole from a main borehole using such a drilling system comprises positioning the drilling assembly in the main borehole at a location of interest using the tubular conveyance; anchoring the drilling assembly in the main borehole using the anchor unit; operating the drilling unit to drill a lateral borehole from the main borehole; retrieving the drilling unit from the lateral borehole; releasing the anchor unit; and moving the drilling assembly to another location.

System and method for drilling lateral boreholes

A drilling system includes integral drill bit body and logging while drilling tool body portions. There are no threads between the drill bit and the LWD tool. In one exemplary embodiment the drilling system includes a unitary tool body, i.e., a tool body formed from a single work piece. In another exemplary embodiment the drill bit body portion is welded to the LWD tool body portion. At least one LWD sensor is deployed in the drill bit. The drilling system enables multiple LWD sensors to be deployed in and near the bit (e.g., on both the side and bottom faces of the bit). The absence a threaded connection facilitates the placement of electrical connectors, LWD sensors, and electronic control circuitry at the bit.

Drilling system for making LWD measurements ahead of the bit

A logging while drilling tool includes a directional resistivity antenna and an antenna shield having. The shield has at least one slot having at least one electrically open end formed therein. The antenna shield may include a base portion and a plurality of spaced apart fingers extending away from the base portion such that the finger ends are electrically isolated from the tool body and from one another. The antenna shield may alternatively include a plurality of spaced apart plates that are electrically isolated from the tool body and from one another. These antenna shields have been found to provide suitable physical protection for sensitive antenna components while at the same time being substantially transparent to both z-mode and x-mode electromagnetic waves.

Directional resistivity antenna shield

Systems and methods for downhole communication and measurement utilizing an improved metallic tubular having an elongated body with tubular walls and a central bore adapted to receive a run-in tool. The tubular including slotted stations to provide through-tubular signal transmission and/or reception. Hydraulic isolation between the interior and exterior of the tubular is provided by pressure barrier means at the slotted stations. Sensors and/or sources are mounted on the run-in tool, which is adapted for transmission through a drill string to engage within the tubular in alignment with the slotted stations. A run-in tool configuration includes a modulator for real-time wireless communication with the surface and/or remote downhole tools. A tubular and run-in tool configuration also includes inductive couplers for wireless signal data transfer. A method for measuring a formation characteristic utilizing a run-in tool adapted with an interchangeable end segment for multi-mode downhole transport. Methods for sealing an opening on the surface of a tubular having an elongated body with tubular walls and a central bore.

Retrievable formation resistivity tool

A logging tool includes a tool body; a simple transmitter comprising a single antenna disposed on the tool body; four simple receivers, each comprising a single antenna, disposed on the tool body and spaced apart from the simple transmitter to form four arrays; and an electronic module for controlling operation of the four arrays, wherein the simple transmitter is configured to generate a magnetic field having a transverse component, wherein each of the four simple receivers is sensitive to the magnetic field generated by the simple transmitter, and at least one of the four simple receivers is sensitive to the transverse component of the magnetic field generated by the simple transmitter, and wherein the four arrays are configured to provide measurements at least three depths of investigation.

Apparatus and methods for determining isotropic and anisotropic formation resistivity in the presence of invasion

Methods for sealing openings in tubulars

A logging tool includes a tool body; a simple transmitter comprising a single antenna disposed on the tool body; four simple receivers, each comprising a single antenna, disposed on the tool body and spaced apart from the simple transmitter to form four arrays; and an electronic module for controlling operation of the four arrays, wherein the simple transmitter is configured to generate a magnetic field having a transverse component, wherein each of the four simple receivers is sensitive to the magnetic field generated by the simple transmitter, and at least one of the four simple receivers is sensitive to the transverse component of the magnetic field generated by the simple transmitter, and wherein the four arrays are configured to provide measurements at at least three depths of investigation.

Growing community of inventors

Sugar Land, TX, United States of America

Stephen D Bonner