A method and apparatus for selective connection of a first fluid communication region to a further fluid communication region at a subsea location and a flexible pipe are disclosed. The apparatus comprises a valve body that includes a primary passageway extending from a first port of the valve body, and connectable to a first fluid communication region, to a further port of the valve body, connectable to a further fluid communication region, the valve body comprising a channel intersecting the primary passageway and extending between an open channel end and a closed channel end; at least one slidable member comprising a slidable body locatable in the channel and comprising a slidable member fluid passage extending through or around the slidable body; and at least one biasing element locatable proximate to at least one of the open channel end or closed channel end, for biasing the slidable body towards the open channel end; wherein the slidable member is slidable along a longitudinal axis of the channel responsive to a local environmental pressure provided at the open channel end.

The present disclosure relates to the technical field of multilateral well drilling, and proposes an integrated whipstock. The integrated whipstock includes a setting body; a whipstock body, provided on the setting body and having a whipstock face; a window mill, located at one side of the whipstock face; and screws, connecting the whipstock body to the window mill, where the whipstock face is provided with slots, and the window mill is provided with protrusions, and the protrusions are configured to be snapped into the slots. With the above technical solution, the present disclosure solves the technical problems in the related art that the integrated whipstock cannot go downhole smoothly and the screws are not easy to be sheared during the setting process.

A release tool can include an inner mandrel, an electric motor assembly, and an engagement member. The inner mandrel is displaceable by the electric motor assembly between a position in which the inner mandrel supports the engagement member and prevents separation of portions of the release tool, and another position in which the engagement member is not supported by the inner mandrel and separation of the portions of the release tool is permitted. A method of separating portions of a release tool in a well can include transmitting an electrical signal to an electrical motor assembly of the release tool, displacing an inner mandrel of the release tool in response to the transmitting, and separating the portions of the release tool after the displacing.

A downhole tool for connecting with a conveyance line. The downhole tool may be or comprise a connector assembly operable to connect to the line. The connector assembly may include a first connector, a second connector, a latching member, and a rotatable member. The first connector and the second connector may be configured to accommodate the line therebetween. The latching member may be latched against the first connector. The rotatable member may be operatively connected with the latching member such that rotation of the rotatable member with respect to the latching member causes relative axial movement between the latching member and the rotatable member thereby forcing the first connector and the second connector toward each other to compress the line therebetween to therefore connect the connector assembly to the line.

A disconnect device for use as part of a downhole assembly in an oil or gas well. In one embodiment, the device comprises a lower receptacle assembly comprising a recess profile; an upper assembly comprising: a shaft comprising a fluid passage, a collet comprising collet fingers, a piston, a cylinder assembly, a pressure chamber disposed radially between the shaft and the cylinder assembly, and a spring, wherein the piston is selectively movable into three positions.

A liner hanger system enables installation of a liner hanger by means of a full bore casing to surface and provides pressure integrity between the casing's inner and outer sides. The liner hanger system comprises a liner hanger, along with an associated liner, coupled to a tieback casing string. The liner hanger and liner are deployed downhole connected to a tieback casing string. Once the liner has been lowered to the position of interest, first the liner hanger is anchored and cemented in position, and then, a packer is set to seal the lower annulus of the liner. The liner hanger system enables operations that used to require a plurality of trips, to be performed in a single trip. It does so without introducing any unwanted limitation to the inner diameter at any point between the wellhead and the end of the liner, and while also allowing for potential decoupling and removal of the tieback casing string from the liner hanger if desired.

A disconnect sub is connected at one end to a pipe for deployment into a well, where the disconnect sub is then connected to a downhole sealing device such as a plug. The disconnect sub comprises a disconnection point that has a lower tensile break value than the rest of the plug, and has a predetermined tensile break value such that the disconnection point will fail when a threshold value of axial tensile load is applied to the disconnect sub. This offers two methods of disconnection of the pipe from the plug after the plug has set—firstly, rotation of the pipe, or if rotation is not possible, overpull of the pipe in excess of the threshold will cause failure of the disconnection point and separation of the pipe from the plug.

A system for automatic detection of drill pipe coupling on a drilling machine is disclosed. The system may include a rotary head, a drill pipe, a display, and a controller. The controller may be configured to: automatically identify a coupling or decoupling condition of the drill pipe; monitor motion and forces associated with the rotary head during a coupling or decoupling action of the drill pipe; automatically identify a fully coupled or fully decoupled condition of the coupling or decoupling action based on the monitored motion and forces of the rotary head; terminate the coupling action based on the identification of the fully coupled or fully decoupled condition; and update the display to indicate the fully coupled or fully decoupled condition of the drill pipe.

A latch system including a plurality of rocker latches, a rocker support, supporting the plurality of rocker latches, and a movement restrictor in operative connection with each rocker latch of the plurality of rocker latches, the movement restrictor allowing or restricting movement of each rocker latch of the plurality of rocker latches relative to the rocker support. A downhole tool including a sleeve movable relative to other portions of the tool, the sleeve having a profile at an uphole end thereof, an actuator runnable into contact with the sleeve, the actuator including the latch. A borehole system including a borehole in a subsurface formation, a string in the borehole, and a latch system disposed within or as a part of the string. A wet connect system including a first connector housing having a first communication line therein, a second connector housing concentrically positionable in the first connector housing and having a second communication line, and a balance piston fluidly connected to the first communication line.

A perforating device includes a release sub, a rotating segment, a first centralizer, a braking segment, a casing collar locator, a traction mechanism, a second centralizer, a flex joint, a power supply segment, a shock absorber, a perforator, and a tail segment, which are in threaded connection sequentially to each other. The first joint assembly includes a first joint, a guide key, a connecting sleeve including a locking groove, a second joint, and an outer pipe; the first joint of the first joint assembly is in threaded connection to the cable bridle, and the second joint is in threaded connection to the outer pipe. The connecting sleeve is disposed inside the outer pipe and is connected to the first joint through the guide key. The second joint assembly includes a plurality of locking claws, a third joint, and a head.