Processes for injection of fluids into a wellbore via drill pipe. In some embodiments, the process can include positioning a downhole apparatus on a drill pipe. The process can also include placing the downhole apparatus at a desired station depth within a wellbore. The process can also include attaching a cable to the downhole apparatus from an up-hole environment. The process can also include setting at least one packer to seal a space between at least a portion of the downhole apparatus and an inner surface of the wellbore. The process can also include introducing a fluid to the downhole apparatus through the drill pipe and using a pump to inject at least a portion of the fluid into a geological stratum.

A swivel configured to rotationally decouple an upper section of a work string from a lower section of the work string. The swivel includes an upper body coupled to a lower body by a ring member and a plurality of shearable members. The lower body has a plurality of teeth members that engage a plurality of teeth members of the ring member. Rotation of the upper body is transmitted to the lower body by the ring member. The upper body is rotatable relative to the lower body when the shearable members are sheared.

A linear actuator having a power rod supported by movable supports is disclosed. The movable supports can provide support to the power rod to avoid buckling of the power rod under large compressive forces. The movable supports are designed to move towards (e.g., by a biasing mechanism) a first position that minimizes the unsupported length of the power rod, but are capable of being displaced by the power rod during extension of the power rod. Examples of movable supports include slidable bearings (e.g., axially slidable) or rotating braces (e.g., rotatable form a supporting position to an out-of-the-way position). Examples of suitable biasing mechanisms include springs and spring members. In some embodiments, hydraulic force is used to move the movable supports.

There is disclosed a tie back float collar for use with a working string to create an extension of a well liner. The tie back float collar consists of a cylindrical housing having upper and lower cylindrical plugs threaded therein, the upper cylindrical plug having a conical left hand threaded receiver coaxially formed thereon with opposite upper and lower openings, the upper opening being larger than the lower opening. The lower cylindrical plug has a conical opening coaxially formed therein with a conical plug coaxially positioned within the conical opening. A biasing spring is coupled to the conical plug and the lower cylindrical plug for biasing the conical plug towards a closed position, the biasing spring positioned above the conical plug.

A downhole drilling tool may include a strain gauge inside a rolling-bearing element. For example, the downhole drilling tool may include a rolling-bearing element having an inner race, an outer race, and one or more bearings disposed between the inner and outer races; and a strain gauge disposed on an interior surface of the rolling-element bearing, the strain gauge including at least one circuit formed by (1) a first substrate and a second substrate defining a gap therebetween and having first conductive fibers and second conductive fibers, respectively, extending therefrom into the gap in an intermingling configuration, (2) an electrical connection between the first and second substrates, and (3) an electrical resistance sensor arranged within the electrical connection.

An apparatus may include a connector sub rigidly securable to a conveyance for running the connector sub along a wellbore and a spool mandrel coupled to a downhole end of the connector sub. The spool mandrel is rotatable with respect to the connector sub. Further, the apparatus may include a control line extending between the connector sub and the spool mandrel. The control line is displaceable to permit rotation of the spool mandrel with respect to the connector sub. Additionally, the apparatus may include at least one biasing member for biasing the spool mandrel to a neutral position with respect to the connector sub.

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 completion system is provided for use downhole in a wellbore that includes a pipe with a restriction inside the pipe. The system includes an upper completion assembly with a mandrel with a mandrel axis and a stinger sub rotatably connected with the mandrel and rotatable around a stinger axis offset from the mandrel axis. The stinger sub also includes a first portion wet-mate connector located in a radially outward portion of the stinger sub. The system also includes a lower completion assembly with a second portion wet-mate connector. The first and second portion wet-mate connectors are connectable downhole. Further, rotation of the stinger sub around the stinger axis rotates and moves the radially outward portion radially inward with respect to the mandrel axis. Doing allows the upper completion assembly to move past a restriction and further downhole into the wellbore.

Downhole rotary steerable drill including a drilling shaft rotatably supported within a housing, the drilling shaft and housing each having a longitudinal axis. The drill can include a releasable locking mechanism for rotationally locking and releasing the drilling shaft relative to the housing, the releasable locking mechanism transitionable between locked and released configurations. The releasable locking mechanism includes a sliding plunger coupled to the housing by a coupling that permits longitudinal reciprocation of the sliding plunger relative to the housing and prevents rotation of the sliding plunger relative to the housing. The releasable locking mechanism can also include pressure-responsive piston that reciprocates between an unactuated configuration and actuated configuration in response to applied pressure from a pressuring pump.

A back-off shot tool system includes a high-pressure resistant charge housing at least partially containing an explosive material. A booster charge is placed adjacent the explosive material to activate the explosive material upon actuation. The high-pressure resistant charge housing is formed from a material that is the material of the high-pressure resistant charge housing is frangible so that it will to withstand high temperatures and pressures, such as a ceramic. In addition, fragment into small pieces that can be process or extracted from the well with fluid that is extracted from the region in which the back-off shot tool is deployed.