Abstract: A multi-barrier seal system, including, a first seal assembly configured to provide a first sealing barrier between an auxiliary line and a mineral extraction system, and a second seal assembly configured to provide a second sealing barrier between the auxiliary line and the mineral extraction system, wherein the second seal assembly is configured to shear through the auxiliary line.

Abstract: A top sub, for connection to a tubing string of a production well, has a first engagement structure, and a mandrel has a second engagement structure. A coupling engages the first and second engagement structures. A housing covers an internal space of the tubing swivel, in which the coupling is located. The coupling includes a first coupling structure having a shape complementary to a shape of the first engagement structure and a second coupling structure having a shape complementary to a shape of the second engagement structure. One of (i) the first engagement structure and the first coupling structure and (ii) the second engagement structure and the second coupling structure has a clutch mechanism to enable the top sub to be rotated in a first direction relative to the mandrel and to rotate the mandrel with rotation of the top sub in a second direction opposite the first direction.

Abstract: An underreamer for increasing the diameter of a bore. The underreamer includes a substantially cylindrical body. A mandrel may extend axially through the body. One or more cutter blocks are movably coupled to the body. A ratio of a height of the cutter block to a diameter of the body is between about 0.35:1 and about 0.50:1.

Abstract: There is disclosed herein drilling apparatus, in particular for use in the field of oil prospecting, comprising: a first tubular member (1, 2, 3); a second tubular member (6, 7, 8, 9) mounted at least partly within the first tubular member so as to be reciprocally free in rotation with respect to the first tubular member about an axis (5); and a drill bit (4) operatively connected to one of the first or second tubular members so as to be rotated in response to the one tubular member being turned in order to effect drilling, characterized in that: the drilling apparatus further comprises a restoring member (18, 36) for applying a forces between the first tubular member and the second tubular member at least in respective first axial directions in response to relative displacement of the first tubular member and the second tubular member in the respective opposite axial directions. Also provided are a tubular assembly and a method of assembling tubular members.

Abstract: A drill rig tong cart is disclosed. The tong cart can include a base portion configured to interface with a drill rig. In addition, the tong cart can include a tong carriage supported by the base portion and configured to interface with a tong for coupling and uncoupling tubulars. The tong carriage can be movable relative to the base portion to alternately position the tong in an engaged position and a disengaged position relative to the tubulars.

Abstract: Example methods and apparatus for determining fluid parameters are disclosed herein. An example method includes disposing a sensor in a first fluid flow passageway. The sensor has a heater and a temperature sensor. The example method further includes flowing a first fluid into the first fluid flow passageway via a second fluid flow passageway and determining a first fluid property value of the first fluid via the sensor when the first fluid is in the first fluid flow passageway. Based on the first fluid property value, a state of an operation is determined.

Abstract: Rotary drill bits may include on or more cutting element assemblies which include a cutter and a mounting system. In one embodiment, the mounting system includes a housing, a first bearing component disposed within the housing, and a second bearing component associated with the cutting element. In certain embodiments, the bearing components may comprise a table of superhard material bonded with a substrate. In one or more embodiments, the bearing components may include bearing surfaces that are arcuate. For example, the bearing surfaces may be substantially spherical (a portion of a sphere). The bearing components may be arranged to act as a radial bearing as well as a thrust bearing for the cutting element, enabling the cutting element to rotate about a longitudinal axis of the cutter, relative to the housing, while also enabling the longitudinal axis of the cutter to be displaced (change angles) relative to the housing.

Abstract: A packer for use in a wellbore includes a packer mandrel. First and second pistons are slidably disposed about the packer mandrel defining first and second chambers therewith. A first activation assembly initially prevents movement of the first piston. A second activation assembly initially prevents movement of the second piston. A seal assembly is disposed about the packer mandrel between the first and second pistons such that actuation of the first activation assembly allows a force generated by a pressure difference between the wellbore and the first chamber to shift the first piston in a first direction toward the seal assembly to radially expand the seal assembly and actuation of the second activation assembly allows a force generated by a pressure difference between the wellbore and the second chamber to shift the second piston in a second direction toward the seal assembly to radially expand the seal assembly.

Abstract: Disclosed are wellbore flow control devices that allow on-site field adjustments to flow characteristics. One autonomous inflow control device (AICD) assembly includes a base pipe defining one or more flow ports and an interior, at least one AICD arranged on the base pipe and having at least one fluid inlet and an outlet in fluid communication with one of the one or more flow ports, and a fluid barrier configured to be arranged about the at least one AICD by a well operator on-site and configured to isolate the at least one AICD from an influx of fluid during operation.

Abstract: Articles comprising at least a portion of an earth-boring tool include at least one insert and a solidified eutectic or near-eutectic composition including a metal phase and a hard material phase. Other articles include a solidified eutectic or near-eutectic composition including a metal phase, a hard material phase and a coating material in contact with the solidified eutectic or near-eutectic composition.

Abstract: A method of increasing a roughness of coiled tubing injector blocks that includes providing a pair of gripper blocks each having a gripper surface configured to grip coiled tubing within an injector head and increasing a first roughness on the gripping surfaces to a second roughness. A coating may be applied to the gripping surfaces to increase the roughness. The coating may be chromium carbide, molybdenum boride, iron boride, titanium boride, or a transitional metal boride. The gripping surfaces may be treated to increase the roughness to a second roughness. The gripping surfaces may be blasted by abrasives or shot peened to increase the roughness. The second roughness may be greater than 20 ?m. A system to inject coiled tubing into a wellbore may include an injector head, coiled tubing, and at least two gripper blocks having a gripping surface with a roughness of at least 20 ?m.

Abstract: An umbilical manipulator arm for positioning control lines for being secured to a plurality of tubular strings being made up and run into a dual completion wellbore includes a carriage movable on a base that is securable to a rig floor adjacent to two tubular strings. An umbilical manipulator arm is coupled to the carriage and movable relative to the carriage between a pusher arm retracted position distal to a tubular string and a pusher arm engaged position proximal to a tubular string. The carriage is movable between a carriage first position proximal to a first tubular string and a carriage second position proximal to a second tubular string. The umbilical manipulator arm can be used to position control lines for being secured to the plurality of tubular strings as they are being made up and run into the wellbore.

Abstract: The present disclosure describes various embodiments, as well as features and aspects thereof, of an improved drill bit assembly for a percussion boring system. More specifically, one non-limiting embodiment of an improved drill bit assembly for a percussion boring system comprises a bit and a product engagement member. The bit comprises a slant faced head and at least one exhaust port. The product engagement member comprises a product coupling portion and at least one fluid restriction portion. This improved drill bit assembly is such that, when the product engagement member is detachably engaged with the slant faced head of the bit, a first portion of the fluid stream expelled from the bit is directed substantially forward of the slant faced head and a second portion of the fluid stream is directed substantially rearward from the slant faced head.

Abstract: Expandable reamers are configured to operate in a first, retracted state in which a plurality of blades is in a retracted position when a sliding sleeve is in a first sleeve position and a seat is in a first seat position, to operate in a second, extended state in which the plurality of blades is movable to an extended position when the sliding sleeve is in at least a second sleeve position and the seat is in the first seat position, and to operate in a third, retracted state in which the plurality of blades is returned to the retracted position when the sliding sleeve is in the at least a second position and the seat is in a second seat position.

Abstract: A well pump assembly has a number modules, including a pump and a motor, secured together. Each of the modules has a housing, and at least one of the modules has a neck of reduced diameter relative to the housing. A clamp is secured around the neck. The clamp has a dovetail groove extending around and within the outer surface of the clamp. An accessory member protrudes radially outward from the outer surface of the clamp and has an inner portion located in the groove. A threaded fastener secures the accessory member to the clamp. The accessory member is slidable along the groove to a selected orientation prior to tightening the fastener.

Abstract: A drill bit may include a matrix bit body and a plurality of cutting elements coupled to an exterior portion of the matrix bit body, wherein the matrix bit body includes matrix particles and precipitated intermetallic particles dispersed in a binder, at least some of the matrix particles having a diameter of 50 microns or greater, and at least some of the precipitated intermetallic particles having at least one dimension of 1 micron to 30 microns.

Abstract: A fill up tool includes a mandrel; a primary sealing member disposed around the mandrel; and a selectively operable secondary sealing member activated by rotation of the mandrel. In another embodiment, the selectively operable secondary sealing member is activated using hydraulic pressure.

Abstract: A cylinder assembly for use as a cylinder comprises an upper outer tubular cylinder and a lower outer tubular cylinder and a stationary sealing ring retained between the upper and lower outer cylinders slideably receiving an inner tubular piston having upper and lower sealing flanges to create upper and lower fluid chambers. Pressurized fluid is selectively directed through flow conduits in the sealing ring into the upper or lower fluid chamber as desired to move the inner tubular piston upward and downward. The upper tubular cylinder supports an attached bearing table and travelling slips. A pipe guide for supporting a length of pipe is positioned in the lower outer tubular cylinder. A mechanism rotating a pipe and pipe string is also provided.

Abstract: In one aspect, a pressure differential device including: an inlet; an outlet; and a fluid restricting member fluidly associated with the inlet and the outlet, wherein the fluid restricting member is configured to provide a first backpressure at a first setting and a second plurality of backpressures at a plurality of second settings. In another aspect, a method to control backpressure including: providing a fluid line with an inlet fluid flow; supplying the inlet fluid flow into a pressure differential device; expelling an outlet fluid flow out of the pressure differential device; pressurizing the inlet fluid flow to a first backpressure at a first setting of the pressure differential device; pressurizing the inlet fluid flow to a second plurality of backpressures at a plurality of second settings of the pressure differential device.

Abstract: A tool for creating impressions of downhole objects comprising a cylindrical outer casing, a top plate, a plunger, an end plate, a lever, a pressure lock plate, a pressure base, a main spring platform, a main spring, and a plurality of elongated rods. The elongated rods extend from beneath the main spring platform through the pressure lock plate, the pressure base, and the end plate. Each elongated rod is surrounded by a rod spring and a collar. The rod spring extends from the bottom of the pressure base to the collar. The pressure lock plate moves laterally when the lever pivots from a locked to an unlocked position, thereby aligning the plurality of holes in the pressure lock plate with the plurality of holes in the pressure base and enabling the elongated rods to move longitudinally within the tool.