Abstract: A whipstock assembly (12) for use in deviating a wellbore (10) of a well is disclosed, the whipstock assembly comprising a whipstock (18) having an inclined deflection surface (20); a milling assembly (14) comprising a mill (16) for milling a window (49) in a wall (48) of the wellbore and forming a rathole (50) extending from the wellbore; a releasable joint (22; 122) 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 (188) 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 (190) associated with the at least one sensor, for communicating data relating to the at least one parameter to an operator of the milling assembly.

Abstract: A whipstock assembly (12) for use in deviating a wellbore (10) of a well is disclosed, the whipstock assembly comprising a whipstock (18) having an inclined deflection surface (20); a milling assembly (14) comprising a mill (16) for milling a window (49) in a wall (48) of the wellbore and forming a rathole (50) extending from the wellbore; a releasable joint (22; 122) 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 (188) 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 (190) associated with the at least one sensor, for communicating data relating to the at least one parameter to an operator of the milling assembly.

Abstract: A whipstock assembly (12) for use in deviating a wellbore (10) of a well is disclosed, the whipstock assembly comprising a whipstock (18) having an inclined deflection surface (20); a milling assembly (14) comprising a mill (16) for milling a window (49) in a wall (48) of the wellbore and forming a rathole (50) extending from the wellbore; a releasable joint (22; 122) 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 (188) 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 (190) associated with the at least one sensor, for communicating data relating to the at least one parameter to an operator of the milling assembly.

Abstract: A device and method to measure strain in a work string during completion operations. The device can include a tubular body with multiple recesses in an outer surface, with strain sensors positioned in some of the recesses. The device can include a fluid pulser configured to communicate data received from the strain sensors to a surface controller via fluid pulse telemetry, with the fluid pulser positioned within one of the multiple recesses. The strain sensors can measure compression, tension, and/or rotational torque in the work string and communicate the sensed data to the surface for evaluation. The device can include a through-bore that extends through the body and has a substantially constant inner diameter for delivering a ball through the device to operate other downhole wellbore tools.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: Methods of monitoring a force applied to a component (28) in a wellbore (12) following drilling and during a subsequent operation. Methods comprising: providing a string of tubing (35) including a tubular member (46) having at least one sensor (48) for measuring the strain in the tubing, and a device (50) 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.

Abstract: 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.

Abstract: 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 (42) for determining the depth and orientation of a feature (24, 26, 28) in a wellbore (12) containing a ferrous tubing (14) is disclosed, the device comprising: at least one magnetic field sensor (44) 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 (48) for determining the orientation of the device within the wellbore.

Abstract: 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 (130m) is disclosed which comprises: a tubing wall (32m), an internal fluid flow passage (30m), and at least one window (154m) pre-formed in the wall of the tubing; a device (34m) for selectively generating a fluid pressure pulse, the device located at least partly in a space (36m) provided in the wall of the tubing; and a coupling (190) for receiving a deflection tool (192) so that the deflection tool can be secured to the tubing and employed to divert a downhole component (202) through the window in the tubing wall.

Abstract: 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.

Abstract: 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.

Abstract: 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.

Abstract: Methods of monitoring a force applied to a component (28) in a wellbore (12) following drilling and during a subsequent operation. Methods comprising: providing a string of tubing (35) including a tubular member (46) having at least one sensor (48) for measuring the strain in the tubing, and a device (50) 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.

Abstract: An example apparatus for generating downhole fluid pressure pulses includes a tubular housing defining an internal fluid flow passage and providing a housing wall having an internal surface and an external surface. The apparatus also includes a device for selectively generating a fluid pressure pulse, the device being mounted in an aperture defined in the housing wall and being movable between a retracted position, where the device is seated within the aperture, and a radially extended position, where the device extends at least partially beyond the external surface.

Abstract: 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, 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, 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.

Abstract: 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.

Abstract: 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.