Abstract: A valve arrangement is for a downhole apparatus having a tubular body having first and second ports in a wall thereof. The valve arrangement comprises a valve member that comprises a first port associated with the first port of the tubular body; and a second port associated with the second port of the tubular body. The valve arrangement is configurable to be locked in a first configuration with the tubular body, such that the first port is closed and the second port is closed. The valve arrangement is configurable to be locked in a second configuration with the tubular body, such that the first port is open and the second port is closed. The valve arrangement is configurable to be locked in a third configuration with the tubular body, such that the first port is closed and the second port is open.

Abstract: A valve arrangement is for a downhole apparatus having a tubular body having first and second ports in a wall thereof. The valve arrangement comprises a first valve arrangement comprising a first valve member associated with the first port of the tubular body; and a second valve arrangement comprising a second valve member associated with the second port of the tubular body. The first valve arrangement and the second valve arrangement are configurable to lock in a first configuration with the tubular body, such that the first port is closed and the second port is closed; to lock in a second configuration with the tubular body, such that the first port is open and the second port is closed; and to lock in a third configuration with the tubular body, such that the first port is closed and the second port is open.

Abstract: A method comprising operating a first valve arrangement and a second valve arrangement from a locked first configuration, in which the first port is closed and the second port is closed, to a locked second configuration, in which the first port is open and the second port is closed, wherein the first valve arrangement comprises one or more locking devices configured to lock a first valve member of the first valve arrangement in place relative to the tubular body. The method comprising operating the first valve arrangement and the second valve arrangement from the locked second configuration to a third configuration, in which the first port is closed and the second port is open.

Abstract: A valve arrangement is for a downhole apparatus having a tubular body having first and second ports in a wall thereof. The valve arrangement comprises a first valve arrangement associated with the first port and comprising a first valve; and a second valve arrangement associated with the second port comprising a second valve. The valve arrangement is configurable to lock in a first configuration with the tubular body, such that the first port is closed and the second port is closed; lock in a second configuration with the tubular body, such that the first port is open and the second port is closed; and lock in a third configuration with the tubular body, such that the first port is closed and the second port is open.

Abstract: A method comprises operating a first valve arrangement and a second valve arrangement from a locked first configuration, in which the first port is closed and the second port is closed, to a locked second configuration, in which the first port is open and the second port is closed. The method comprises operating the first valve arrangement and the second valve arrangement from the locked second configuration to a third configuration, in which the first port is closed and the second port is open; and moving the first valve arrangement to a third intermediate configuration between a second intermediate configuration and the third configuration, in which the first valve arrangement is locked, the second valve arrangement is locked and the first and second ports are closed.

Abstract: There is provided a sandscreen joint (110) capable of providing zonal isolation. The ends of the portion of the (110) are capable of extension on activation of the sandscreen (110), including transition areas (135), which are coated with an elastomer sleeve (134). On activation of the sandscreen (110), the sleeve (134) is pushed out into contact with the bore wall and serves to isolate the zone on one side of the activated sleeve (134) from the zone on the other side of the sleeve (134). Thus, the provision of the sleeve (134) on the activated sandscreen (110) may prevent fluid from flowing axially along the bore between the bore wall and sandscreen. This may serve to protect the weave at the transition area (135), preventing axial flow through the transition areas (135).

Abstract: The present invention relates to a downhole apparatus and a valve arrangement for a downhole apparatus having a tubular body having first and second ports in a wall thereof; and a method of operating a valve arrangement of a downhole apparatus. The valve arrangement has at least one locked configuration and the first port provides fluid communication with a tool or a device which is a sand control element having at least one fluid deformable device. The present invention also provides a method of setting a sand control completion, extending the sand control filter element thereof to a wellbore surface and isolating the reservoir from an upper portion of the wellbore.

Abstract: This disclosure may generally relate to drilling operations and, more particularly, to systems and methods for cleaning a drilling fluid as it travels back to the surface from a wellbore. An apparatus may comprise a magnetic body having a longitudinal axis. The magnetic body may comprise a pair of end plates that are spaced along the longitudinal axis and a magnetic unit disposed between the pair of end plates, wherein the magnetic unit is operable to generate a magnetic field. The apparatus may additionally comprise an axle disposed along a longitudinal axis of the magnetic body, wherein the axle is operable to rotate the magnetic body about the longitudinal axis.

Abstract: A tubular has a retracted configuration and an extended configuration. The tubular is initially in the retracted configuration and run into a bore at least partially lined with filter cake. The tubular is extended such that a filter cake-disrupting member mounted on the tubular defines high points or otherwise has an outer surface of varying radial extent for disrupting or disturbing the filter cake.

Abstract: A downhole apparatus including a tubular body, first and second ports in a wall of the body, and a fluid pressure-responsive valve arrangement having a locked first configuration associated with a first pressure in which the first port is open and the second port is closed, an unlocked second configuration associated with a second pressure higher than the first pressure in which the first port is open and the second port is closed, and a third configuration associated with a third pressure lower than the second pressure in which the second port is open and the first port is closed.

Abstract: A method is for use with subterranean formations, such as oil and/or gas reservoirs. In some examples (e.g., production examples), the method improves the production from that formation. Some of the examples of the method describe selecting both an exertive force (e.g., a pressure) to apply at a wellbore, but together with a drawdown pressure at the wellbore to modify operations (e.g., improve production) at that subterranean formation. The selection of one or both of the exertive force and drawdown pressure may be based on the downhole environment at that wellbore, which can include the porosity and/or permeability of a near-wellbore formation radially surrounding a wellbore. The exertive force and drawdown pressure may be specifically selected to modify the porosity and/or permeability of the near-wellbore formation.

Abstract: A sandscreen joint is capable of providing zonal isolation. The ends of a portion of the sandscreen are capable of extension on activation of the sandscreen, including transition areas, which are coated with an elastomer sleeve. On activation of the sandscreen, the sleeve is pushed out into contact with the bore wall and serves to isolate the zone on one side of the activated sleeve from the zone on the other side of the sleeve. Thus, the sleeve on the activated sandscreen may prevent fluid from flowing axially along the bore between the bore wall and sandscreen. This may protect the weave at the transition area, preventing axial flow through the transition areas.

Abstract: A method of injecting fluid into a formation, comprises exerting a mechanical force on a wall of a bore extending through a formation to modify the permeability of the formation; and injecting fluid into the modified formation. The mechanical force is exerted through inflation of at least one pressure deformable member mounted on a base member with a retaining ring.

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: 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.