Abstract: Oil and gas operations according to which a wellhead is operably associated with a wellbore, a valve is operably coupled to the wellhead, opposite the wellbore, a frac line is operably coupled to the wellhead, and a zipper module is operably coupled to the frac line, opposite the wellhead.

Abstract: A horizontal directional drilling machine includes a drill string rotational drive unit having an output member configured to connect with and selectively drive rotation of a drill string, the rotational drive unit including a hydraulic motor. A hydraulic circuit has a configuration that puts the motor in a drive mode to apply torque and a second configuration that puts the motor in a freewheel mode disabled from applying torque. The hydraulic circuit includes a first fluid flow path for connecting the hydraulic motor through a first rotary ball valve to one of an inlet side and an outlet side of a drive pump, and a second fluid flow path for selectively connecting the hydraulic motor through a second rotary ball valve to the other side of the drive pump. In the first configuration, there is no pressure drop across the first and second rotary ball valves.

Abstract: Disclosed embodiments relate to isolation devices for use downhole in a wellbore, for example to isolate a zone of a well. Isolation device embodiments may include a slip, a wedge, a seal element, and a retaining mechanism. The slip may have a run-in position with respect to the wedge and a set position with respect to the wedge. The seal element may be configured to expand radially during movement from the run-in position to the set position. The retaining mechanism may be configured to allow movement of the slip from the run-in position towards the set position, but to lock the slip in the set position. In embodiments, the retaining mechanism may be configured to prevent dislocation of the slip when set, for example forming a retaining cage around the slip.

Abstract: A drilling control system may access a drilling plan for a borehole comprising one or more of planned path for the borehole, drill string information, mud properties, drill bit properties, formation properties, and drill rig properties. The system may receive a plurality of operating parameters from a rig for the borehole including one or more of an observed toolface, a spindle setting, a rate of penetration, a differential pressure, and a weight-on-bit. The system may receive one or more propagation functions for the borehole determined by a model of the drill string. The system may determine one or more spindle changes or block speed changes based at least in part on the propagation functions and the plurality of operating parameters. The system may generate one or more predicted drill properties from a simulator using the one or more spindle changes or the one or more block speed changes.

Abstract: A viscous dampening component is provided for use with a drill bit. The viscous dampening component may include an inertial mass ring configured to surround a shank of a drill bit, a cover configured to surround the inertial mass ring and the shank to position and maintain the inertial mass ring on the shank, and a viscous fluid disposed between the inertial mass ring and the shank. When the inertial mass ring rotates relative to the shank of the drill bit, energy is dissipated within the viscous fluid.

Abstract: A system includes a pressure exchanger configured to exchange pressure between a first fluid and a second fluid. The system further includes a shaft at least partially disposed within the pressure exchanger. The system further includes an electric motor coupled to the shaft. The electric motor is configured to control fluid flow in the pressure exchanger. A controller is configured to receive sensor data from one or more sensors associated with the pressure exchanger and vary proportions of the first fluid and the second fluid entering the pressure exchanger to reduce mixing of the first fluid and the second fluid in the pressure exchanger.

Abstract: Systems and methods for characterizing a subterranean formation that include a drill bit for drilling a deviated wellbore through the formation and that repeatedly changes direction. Also included is a directional drilling system and measurement equipment to detect a property of the formation. A trajectory control system is operable to: receive a well log; determine a property of the wellbore; segment the well log based on the property; and correlate one of the segments with the well log previous to the segment to determine a matching score for the segment. If the matching score is equal to or greater than a minimum threshold, the segment was taken in the formation and at the same stratigraphical true vertical depth (“STVD”). If the matching score is less than the minimum threshold, the segment was not taken in the formation and not at the same STVD and the STVD is estimated.

Abstract: Disclosed embodiments relate to a pulsed-power drilling system, in which a pulsed-power drill is conveyed downhole and operated via coiled tubing. The coiled tubing may be configured to simultaneously transmit power and drilling fluid downhole. For example, the coiled tubing may include a flexible hollow fluid tube configured to transport drilling fluid therein, and a flexible cable tube disposed within the fluid tube. The cable tube may have one or more cable disposed within protective tubing, protecting the cables from drilling fluid in the fluid tube. Methods of making and using such coiled tubing with pulsed-power drills are also disclosed.

Abstract: An insertion tool assembly includes a lubricator and a tubular adapter. The tubular adapter includes a main body with a central bore therethrough. A top end of the adapter can be attached to the lubricator and the bottom end attached to a crown top of a wellhead. The tubular adapter also includes a kill fluid port disposed through a side-wall of the main body. The insertion tool assembly is configured such that, when the BPV is attached to the distal end of the rod and the bottom end of the tubular adapter is attached to the crown top, the BPV can pass through the tubular adapter and into the wellhead through the crown top as the rod is extended from the lubricator, and a kill fluid injected into the kill fluid port can flow through the crown top into the well.

Abstract: Hydrocarbon flow into multi-lateral wells is analyzed by controlled release of tracers from the surface. Hydrocarbons flow into a lateral formed from a wellbore into a subterranean zone. A wellbore production tubing is installed within the wellbore and extends toward the lateral. The wellbore production tubing defines an annulus between an outer surface of the tubing and an inner wall of the wellbore. Hydrocarbons flowing from the lateral into the annulus flow within an internal volume defined by a body attached to the outer surface of the tubing. The hydrocarbons mix with tracers residing within the internal volume. A mixture of the hydrocarbons with the tracers flow out of the internal volume and towards the surface. At the surface, a concentration of the tracers in the mixture flowed to the surface is analyzed. Based on a result of the analyzing, properties of hydrocarbon flow into the lateral are determined.

Abstract: Methods and systems for conveying a WFT via drill pipe within a wellbore penetrating a subterranean formation and setting two packers of the WFT on opposite sides of a zone of interest of the formation, thereby isolating an interval of an annulus between the WFT and a wall of the wellbore. DTT of the formation is then performed by operating two WFT pumps of the WFT to pump fluid from the formation via the isolated interval, through the WFT, and out of the WFT to the wellbore, while operating mud pumps to pump drilling mud into the wellbore and thereby convey a mixture of the drilling mud and the pumped formation fluid through the annulus to a mud gas separator. Gas from the mud gas separator is used to measure a surface production rate of the formation fluid.

Abstract: A method of remediation includes positioning a well tool in a bore of the first wellbore tubular, the well tool having at least one shaped charge and at least one propellant body. The method further includes detonating the shaped charge to generate a jet that forms an opening in a first wellbore tubular and a tunnel at least partially in a cement body, but does not form an opening in a second wellbore tubular. The method also includes igniting the propellant body to generate a gas at a volume and pressure selected to disintegrate the cement body.

Abstract: A method comprises obtaining measurement data of a subsurface formation while drilling a wellbore in the subsurface formation. The method comprises generating a horizontal resistivity model of the subsurface formation at respective depths along the wellbore based on the measurement data. The method comprises generating a vertical resistivity model of the subsurface formation at the respective depths along the wellbore based on the measurement data. The method comprises generating an effective resistivity at the respective depths along the wellbore based on the horizontal resistivity model and the vertical resistivity model to indicate a formation resistivity in each direction of the wellbore. The method comprises performing a drilling operation based on the effective resistivity.

Abstract: Disclosed herein are systems and methods for automating a pump-down stop operation and, more particularly, example embodiments may include an automated pump-down stop system that adjusts a fluid rate and a winch speed before the target depth based on the remaining depth and line speed. An example method for automating a pump-down stop operation of a downhole tool string includes: measuring a depth of the downhole tool string, wherein the downhole tool string is held by a wireline; measuring a wireline tension; measuring a speed of the wireline; measuring a pumping rate; measuring an inclination of the downhole tool string; and regulating automatically a winch controller and a pump controller simultaneously to stop the downhole tool string at a target depth based at least on the measurements of one or more of the depth, wireline tension, speed, pumping rate, and/or inclination.

Abstract: 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.

Abstract: Systems and methods for coupling subsea tubular members together are provided. An apparatus may be used to properly orient and/or provide communication between a first subsea tubular member that is being landed on a second subsea tubular member. An apparatus for coupling subsea tubular members may include an alignment sub and a corresponding alignment member. The alignment sub includes: a generally cylindrical body having one or more fluid, electric, or fiber optic lines extending therethrough, one or more couplings coupled to at least one end of the alignment sub, and an orientation profile disposed on a surface of the alignment sub. The alignment member has a profile designed to interface with the orientation profile of the alignment sub. One of the alignment sub and the alignment member remains stationary while the other rotates relative to the stationary structure.

Abstract: An apparatus, method, and system for inserting and securing a high pressure transition tube of a fluid transfer tool assembly into a positive position whereby the seal element is packed off in the wellhead set point. Once attached the transition tube is pushed to contact the bit guide, secondary seal or bore machine prep. A lower nose compression seal is seated against transition tube and compressed using an energizer seal to isolate and protect lower pressure wellhead and well control equipment from the higher rated frack pressures or pushing the transition tube and lower nose isolation compression seal to contact the bit guide, secondary seal or bore prep. Pressure is applied to push a seal against the lower and upper compression ring locking them in place preventing movement to form a compression seal and isolating the high pressure passing through the transition tube protecting the wellhead assembly and well control equipment.

Abstract: An insert valve installed, at least partially, in a safety valve that includes a flow port disposed on an exterior of the insert valve, a poppet configured to control a fluid flow through the flow port, a piston rod, disposed uphole from the poppet, configured to move the poppet past at least part of the flow port, and a hydraulic control port configured to control movement of the piston rod.

Abstract: A method is provided for forming a wellbore extending from a surface into an underground reservoir of magma. The method includes drilling a primary borehole from the surface into the underground reservoir of magma and drilling a secondary borehole extending from the primary borehole and further into the underground reservoir of magma.

Abstract: A technique facilitates improved actuation and use of packers which may be disposed along a well string placed in a borehole, e.g. a wellbore. Each packer may be constructed with or mounted about a tubing and may further comprise a mandrel disposed about or integrally formed with the tubing. The packer may further comprise a sealing element mounted about an expandable metal bladder which, in turn, is secured around the mandrel via suitable connections, e.g. end connections. The mandrel is constructed with a feedthrough or a plurality of feedthroughs which enable placement of alternate path tubes, hydraulic lines, electric lines, or other components through the packer.