Abstract: A moon-based in-situ condition-preserved coring multi-stage large-depth drilling system and method therefor. The system includes a rotary plate provided inside a lander, an in-situ condition-preserved coring tool provided on a surface of the rotary plate, a space frame provided on a surface of the rotary plate, a working platform provided on a top of the space frame, a mechanical arm provided on a bottom surface of the working platform, and a camera provided on the bottom surface of the working platform, the mechanical arm is fixedly connected to the working platform, and the camera is fixedly connected to the working platform. By controlling the mechanical arm to place the in-situ condition-preserved coring tool on the moon surface, and using the in-situ condition-preserved coring tool to sample the lunar soil on the moon surface, the coring operation problem of the lunar soil is solved.

Abstract: A computer-implemented method including receiving a steering command identifying a tool face orientation in which the steering command is expected to produce an intended steering response of an intended drilling trajectory. The method further includes receiving an actual steering response result of the steering command in which the actual steering response result identifies an actual drilling trajectory. The method further includes storing a dataset comparing the actual steering response result in relation to the intended steering response, determining an uncertainty level of the tool face orientation based on the stored dataset, and outputting a visual representation of steering response with the uncertainty level.

Abstract: An internal assembly (230) for a tool (200) includes a retainer (232) that at least partially defines an axial bore (238). The retainer (232) further defines a port (246) providing a path of fluid communication from an exterior of the retainer to the bore (238). The internal assembly (230) also includes an electromagnet (250) coupled to the retainer (232). The electromagnet (250) is configured to actuate between an on state and an off state and to attract magnetic debris in a fluid when in the on state. The internal assembly (230) also includes a sleeve (260) that is configured to be positioned downstream from the retainer (232). The sleeve (260) at least partially defines the bore (238). The sleeve (260) further defines a port (262) that provides a path of fluid communication from the bore (238) to an exterior of the sleeve (260). The internal assembly (230) also includes a valve (270) configured to be positioned downstream from the port (262) in the sleeve (260).

Abstract: A gas mitigation system for controlling the amount of gas that reaches a submersible pumping system deployed in a wellbore includes a well zone isolation device disposed in the wellbore between the submersible pumping system and a gas collecting region. The gas mitigation system further includes a back pressure control module and a gas vent line extending from the gas collecting region through the well zone isolation device to the back pressure control module. A liquid intake line extends from the well zone isolation device to an area of the wellbore upstream from the gas collecting region.

Abstract: A method for determining a screen break may include obtaining a fluid stream after a screening system in a drilling process; placing the fluid stream into a screen break detector; obtaining a pressure within a well of the screen break detector when the screening system is in a first state; obtaining a pressure within the well of the screen break detector when the screening system is in a second state; determining a differential pressure within the well of the screen break detector obtained when the screening system is in the second state compared to the pressure when the screen break is in the first state; and transmitting a notification to an operator when the pressure within the screen break detector obtained when the screening system is in the second state is greater than the pressure within the screen break detector when the screening system is in the first state.

Abstract: A release device for a jarring tool includes a collet positioned between the mandrel of the jarring tool and a trigger sleeve. At least one end of the collet is in contact with a precompressed spring via a bushing. In order for the jarring tool to operate, a force greater than the precompressed force of the spring must be applied to the mandrel so that the collet can move in axial direction against the spring thereby releasing the mandrel.

Abstract: A downhole tool comprises a hollow body having a wall and a port in the wall, and a closing sleeve movable relative to the body to open and close the port. A seal is provided between the body and the sleeve and is configured to hold differential pressure. An isolation member may be deployed in the tool to isolate the seal from differential pressure and close the port. The isolation member may be deployed following initiation of a tool activation process, a successful outcome of the process being translating the closing sleeve and closing the port, and positioning the seal to hold a differential pressure. If it is detected that the outcome has not been achieved, the isolation member is deployed to isolate the seal from differential pressure and close the port.

Abstract: A hydraulic fracturing tree wing is formed with a studded hydraulic valve next to a manual valve. The stud-to-flange connection allows for a shorter, lighter wing. The studded hydraulic valve maybe a gate valve that includes a T-slot coupling between an operating stem and the gate. A bonnet seal ridge may be formed to withstand undue deformation during operation that wears or destroys seals. A method for forming a hydraulic fracturing tree assembly includes using a flanged manual valve with a studded hydraulic valve. Other valves and methods are presented.

Abstract: An apparatus for use in a wellbore includes a drill string section, a drive shaft disposed in the drill string section, a bearing assembly connected to the drive shaft, and an alignment assembly connecting the bearing assembly to the drill string section. The alignment assembly has a first alignment member and a second alignment member slidingly engaging one another to allow at least a portion of the bearing assembly to tilt relative to the drill string section. A related method includes the steps of positioning a drive shaft in a drill string section; connecting a bearing assembly to the drive shaft using the alignment assembly, the alignment assembly having a first alignment member and a second alignment member; and allowing at least a portion of the bearing assembly to tilt relative to the drill string section using the alignment assembly by having the first alignment member and the second alignment member slidingly engage one another.

Abstract: A fluid control device includes a filtration component, which has a porous filtration medium. The filtration medium contains a shape memory thermoset material foamed with a polymeric microsphere and a gas-producing chemical foaming agent. The porous filtration medium is configured to be compacted from an initial shape to a compacted shape, deployed in the borehole, and subsequently expanded to conform to a surface of the borehole.

Abstract: An extrudable ball seat (36) is configured to be secured along a well tubing (34). The extrudable ball seat (36) comprises a larger diameter section (42) and a smaller diameter (44) section connected by a conical section (46). The conical section (46) has an internal seating surface (48) for receiving a corresponding element, e.g. a ball (52), in sealing engagement. The extrudable ball seat (36) facilitates controlled extrusion of the element following a pressure actuation procedure by providing the smaller diameter section (44) with sufficient ductility to enable extrusion of the element under an increased predetermined pressure. Additionally, the extrudable ball seat comprises at least one notch (56), e.g. a plurality of grooves (58), positioned to initiate crack propagation and thus extrusion of larger elements.

Abstract: Example systems, apparatus, and methods are described for providing continuous backup rings that are swaged into closed gland seal grooves to reduce extrusion of elastomeric sealing elements in packers. In an example embodiment, the closed gland sealing system includes a mandrel body having a cylindrical outer surface. A seal mandrel portion of the mandrel body is defined by an annular recess in the mandrel body that extends radially around the substantially cylindrical outer surface to form a closed gland groove. A sealing element is positioned in the closed gland groove and extends radially around the seal mandrel portion. Further, a continuous backup ring is positioned in contact with the sealing element in the closed gland groove that also extends radially around the seal mandrel portion.

Abstract: A technique facilitates use of an inductive coupler assembly with casing, e.g. well casing. An inductive coupler is formed as a female inductive coupler with an inductive coil. The inductive coupler is constructed for sliding movement along an exterior of the casing so that it may ultimately be positioned and secured at a suitable location along the casing. The inductive coupler is designed for connection with an electrical device, e.g. a sensor. The inductive coupler facilitates the transfer of sensor data and/or power signals across the casing. Signal transfer across the casing is further enabled by a male inductive coupler positioned within the casing at a location which allows it to cooperate with the exterior, female inductive coupler.

Abstract: A method for determining conditions in a wellbore extending through a subterranean formation includes deploying a plurality of sensor pods in the wellbore, wherein each sensor pod includes a housing and a plurality of sensors disposed in the housing. The method also includes measuring and recording a plurality of pressures and a plurality of temperatures with plurality of sensors of each sensor pod, dissolving the housings of the pods to release the plurality of sensors from the pods after measuring and recording the plurality of pressures and the plurality of temperatures, and lifting the sensors to the surface.

Abstract: A casing patch system comprising a base tubular with two anchor/seals coupled to the base tubular and an expansion tool comprising two expansion devices positioned such that upon expansion of the first anchor/seal, the second expansion device engages the second anchor/seal. In another embodiment, the expansion device comprises two swages coupled to a shaft at a distance between them approximately equal to the length of the anchor/seal. The swage diameters are selected such that the expansion forces of the anchor/seal by front and back swages are approximately equal.

Abstract: A hydrocarbon recovery process for recovering hydrocarbons from a hydrocarbon-bearing formation includes preheating a pipe coupling a steam generation facility to a well for injection of steam into the hydrocarbon-bearing formation by controlling heat traces extending along the pipe, directing steam generated at the steam generation facility, through the pipe after preheating, and injecting the steam into the hydrocarbon-bearing formation via the well, and controlling heat input to the pipe by controlling the heat traces extending along the pipe as the steam travels through the pipe. Fluids are produced from the hydrocarbon-bearing formation.

Abstract: Systems and methods determine friction in a borehole during drilling operations. A drilling system applies oscillatory angular movement at the top of a drill string in a wellbore during drilling by the drilling system, and measures a torque applied to the drill string and an angular position of the drill string. Based on the measured torque and the measured angular position, the drilling system computes a friction between the borehole and the drill string. This can be repeated during drilling of the wellbore to determine multiple friction values, corresponding to various depths of the borehole. Based on the computed friction, the drilling system can perform one or more actions resulting in modified drilling operation. The systems and methods also include oscillating a casing in the borehole, measuring the torque and angular position of the casing, and determining a friction value, which can be repeated to develop a wellbore friction profile.

Abstract: A technique facilitates operation of a valve system a having combined valve such as a combined formation isolation valve and a circulating valve. In well operations, the valve system is deployed downhole into a wellbore on a tubing string. The formation isolation valve and the circulating valve are operable independently via inputs, e.g. hydraulic inputs provided through less than three hydraulic control lines. The formation isolation valve and the circulating valve may be coupled by a mechanical linkage, which enables operation of the two valves via the hydraulic control lines. In some embodiments, the formation isolation valve and the circulating valve may be operated via an integrated shifting tool.

Abstract: A shaft in an electrical submersible pumping system is prevented from rotation in a backspin direction, which is in a direction opposite from its typical forward rotation during normal operation. Backspin rotation is prevented with a device that includes teeth coupled to the shaft and a stationary pawl disposed in a rotational path of the teeth. Each tooth has a forward surface that contacts the pawl during forward rotation of the shaft, the forward surfaces are each configured with a profile to slide along and past the pawl without impeding shaft rotation. Rotation in the backspin direction engages the pawl with rearward surfaces of the teeth, which are configured to impede shaft rotation when engaged. Fluid being handled by the pumping system flows through a passage in the device and absorbs friction generated thermal energy from the device.

Abstract: A wellbore tool assembly to release stuck pipe includes a tubular that includes an outer wall, an inner wall and an annular compartment defined between the outer wall and the inner wall. A quantity of acid is carried within the annular compartment of the tubular. Multiple ports are formed in the tubular. Each port fluidically connects an inner volume of the tubular with a volume outside the tubular through the annular compartment. The assembly includes a ball seat disposed within the tubular. The ball seat is configured to receive a ball dropped into the tubular. The multiple ports are configured to switch between an open position and a closed position. When in the open position, the multiple ports permit flow of the acid from the annular compartment to the formation. When in the closed position, the multiple ports prevent fluid flow from the annular compartment to the formation.