Halliburton Manufacturing and Services Limited

Halliburton Energy Services, Inc.

Maxwell Downhole Technology Ltd.

Oiltoolsteq Ltd

Cool Group Limited

William Brown-Kerr

Bruce Hermann Forsyth McGarian

Simon Benedict Fraser

Bruce Hermman Forsyth McGarian

John Knight

Bruce H McGarian

Andrew John Watson

A whipstock assembly () for use in deviating a wellbore () of a well is disclosed, the whipstock assembly comprising a whipstock () having an inclined deflection surface (); a milling assembly () comprising a mill () for milling a window () in a wall () of the wellbore and forming a rathole () extending from the wellbore; a releasable joint () by which the milling assembly is releasably connected to the whipstock, so that the milling assembly can be separated from the whipstock within the wellbore and subsequently deflected towards the wellbore wall by the deflection surface of the whipstock; at least one sensor () provided in the milling assembly, for measuring at least one parameter of the rathole, the at least one parameter relating to a trajectory of the rathole; and a communication device () associated with the at least one sensor, for communicating data relating to the at least one parameter to an operator of the milling assembly.

Whipstock assembly

A downhole assembly includes a tool-orienting device including an operating unit that obtains downhole measurements and a pulse-generating device that transmits the downhole measurements to orient a downhole tool. A restrictor sub is coupled to the tool-orienting device and includes a nozzle that restricts fluid flow therethrough, and a circulating valve is coupled to the restrictor sub and includes a nozzle that restricts fluid flow therethrough. A liner running tool is coupled to the circulating valve to convey a liner and a pressure-activated tool into the wellbore. The pulse-generating device operates with a fluid at a first pressure and the restrictor sub is actuatable by increasing the first pressure to a second pressure. The circulating valve is actuated by the fluid at a third pressure and the pressure-activated tool is activated by increasing third pressure to a fourth pressure.

Orientation and actuation of pressure-activated tools

An apparatus for generating a fluid pressure pulse downhole includes an elongate tubular housing defining an internal fluid flow passage. A first device is coupled to the housing for controlling a flow of fluid along a first flow path that communicates with the internal fluid flow passage to generate a first fluid pressure pulse. A second device coupled to the housing for controlling a flow of fluid along a second flow path that communicates with the internal fluid flow passage to generate a second fluid pressure pulse. The first and second devices are releasably mounted in corresponding spaces defined in a wall of the housing, and the first and second devices each house a valve having a valve element and a valve seat. The valve being actuatable to control the flow of fluid along the first and second flow paths, respectively.

Downhole apparatus and method

Downhole assemblies including a plurality of tubular members extendable within a wellbore and defining a through bore. A telemetry device is positioned within a wall of one of the plurality of tubular members and has a secondary flow path defined therethrough and a valve element engageable with a valve seat provided at an upper end of the secondary flow path. The secondary flow path extends between an inlet and an outlet, both of which fluidly communicate with the through bore and are defined in the one of the plurality of tubular members. A flow restrictor is located within the through bore and is axially positioned between the inlet and the outlet of the secondary flow path. The valve element is actuatable to control fluid flow through the secondary flow path to selectively generate a fluid pressure pulse.

Well construction real-time telemetry system

Methods of monitoring a force applied to a component () in a wellbore () following drilling and during a subsequent operation. Methods comprising: providing a string of tubing () including a tubular member () having at least one sensor () for measuring the strain in the tubing, and a device () for transmitting data to surface and which is operatively associated with the sensor. Running the string of tubing into the wellbore; monitoring the strain in the tubing measured by the sensor and compensating for the strain. Performing an operation in the well employing the tubing, involving the application of a force to the component in the wellbore; monitoring the resultant change in strain in the tubing measured by the sensor; and transmitting data relating to the resultant change in strain to surface using the data transmission device, to facilitate determination of the force applied to the component.

Monitoring and transmitting wellbore data to surface

An example method includes introducing a string of tubing into a wellbore to perform a primary operation, the string of tubing including at least one sensor for measuring strain and at least one device operatively associated with the at least one sensor. The method further includes translating the string of tubing relative to the wellbore, imparting a load on the string of tubing when the tubing becomes stuck in the wellbore at a stuck point, and thereby generating strain in the string of tubing above the stuck point. Additionally, the method includes measuring the strain with the at least one sensor, transmitting data indicative of the strain to a surface location with the at least one device, and determining a position of the at least one sensor in the wellbore, as based on the strain, relative to the stuck point.

Determining stuck point of tubing in a wellbore

The invention relates to a device for determining the depth and orientation of a feature in a wellbore, and to a corresponding method. It also relates to a downhole apparatus for performing an operation in a well comprising a device for determining the depth and orientation of a feature in a wellbore and a device for performing the operation. In an embodiment, a downhole device () for determining the depth and orientation of a feature () in a wellbore () containing a ferrous tubing () is disclosed, the device comprising: at least one magnetic field sensor () for monitoring the inherent magnetic field of the ferrous tubing so that the presence of the feature can be detected; and at least one orientation sensor () for determining the orientation of the device within the wellbore. An output from the at least one magnetic field sensor is correlated with an output from the at least one orientation sensor so that the orientation of the feature detected by the at least one magnetic field sensor within the wellbore can be determined.

Determining the depth and orientation of a feature in a wellbore

The invention relates to a wellbore-lining tubing comprising at least one window pre-formed in the wall of the tubing and a device for selectively generating a fluid pressure pulse, and to a method of forming a lateral wellbore employing such a tubing. In an embodiment, a wellbore-lining tubing () is disclosed which comprises: a tubing wall (), an internal fluid flow passage (), and at least one window () pre-formed in the wall of the tubing; a device () for selectively generating a fluid pressure pulse, the device located at least partly in a space () provided in the wall of the tubing; and a coupling () for receiving a deflection tool () so that the deflection tool can be secured to the tubing and employed to divert a downhole component () through the window in the tubing wall.

Downhole apparatus, device, assembly and method

The invention relates to methods of determining whether a wellbore sealing operation has been performed correctly, and to wellbore-lining tubing which facilitates the determination of whether a wellbore sealing operation has been performed correctly. The invention has a utility in determining whether cement has been correctly supplied into an annular region defined between an internal wall of a wellbore and an external surface of a wellbore-lining tubing located in the wellbore, or whether a packer has been properly set to seal such an annular region. One disclosed method comprises the steps of: locating a wellbore-lining tubing () in a wellbore (), said tubing having at least one pressure sensor (); performing a wellbore sealing operation in an annular region () defined between an external surface of said tubing and an internal surface () of a wall of the wellbore, or between an external surface of said tubing and an internal surface of another wellbore-lining tubing () in which said tubing is located, to seal said tubing in the wellbore; monitoring the pressure of fluid in the annular region using the at least one pressure sensor; and recovering data concerning the pressure of the fluid monitored by the sensor to surface, the pressure data indicating whether the wellbore sealing operation has been performed correctly.

Determining whether a wellbore sealing operation has been performed correctly

A method for obtaining real-time data relating to a well construction activity includes locating wellbore-lining tubing comprising at least one non-magnetic tubing section in a wellbore of a well. At least one downhole parameter is measured at a location external of the wellbore-lining tubing using at least one sensor associated with the non-magnetic tubing section. A magnetic field generating device is positioned within the non-magnetic tubing section and the device is activated to inductively couple the device to the at least one sensor. Data relating to the at least measured parameter is then transmitted through the non-magnetic tubing section to the magnetic field generating device by means of the inductive coupling. The data retrieved from the at least one sensor may then be transmitted to surface using a fluid pressure pulse generating device associated with the magnetic field generating device.

Downhole method and assembly for obtaining real-time data

A downhole tool for generating a fluid pressure pulse, and to a method of generating a fluid pressure pulse downhole. One example being, an improved downhole tool and method for transmitting data signals from a downhole environment to surface, the downhole tool comprising a fluid actuated flow restrictor; a first fluid flow path for flow of actuating fluid to actuate the flow restrictor; a second fluid flow path for flow of actuating fluid to actuate the flow restrictor; and a control member movable between a first closed position where the first fluid flow path is closed and the second fluid flow path is open, and a discrete second closed position where the first fluid flow path is open and the second fluid flow path is closed, for controlling actuation of the flow restrictor to generate a fluid pressure pulse.

Downhole tool and method

There is disclosed an electrically insulating device in the form of a sleeve () for a downhole tool, for electrically insulating a first threaded electrically conductive member in the form of an anchor sub () from a second threaded electrically conductive member in the form of an insulated sub (). An assembly () including the sleeve () has particular use in measurement while drilling (MWD)/logging while drilling (LWD) procedures. In one embodiment, a third member in the form of a threaded electrically conductive sleeve sub () is coupled to the insulated sub by a second sleeve (), to create an insulated gap between the anchor and sleeve subs ().

Growing community of inventors

Aboyne, United Kingdom

William Brown-Kerr