Abstract: A drill pipe speed sensor includes a roller head assembly including an incremental encoder, a roller to contact a drill pipe, and first and second rotating members. The first rotating member is coupled to the roller, the second rotating member is coupled to the incremental encoder, and the first rotating member is coupled to the second rotating member. The sensor also includes a pivot assembly having mounting plates, pivotal arms, first and second mounting members, and a biasing member. The first and second mounting members extend between the mounting plates, which are parallel to each other. The biasing member contacts the mounting members and extends between the mounting members, and the biasing member is parallel to the mounting plates. The pivotal arms extend from the mounting plates to the roller head assembly and pivot relative to the mounting plates, and the first mounting member is coupled to two pivotal arms.

Abstract: A well system includes a well platform including a rig floor, a first rig floor robot and a second rig floor robot positioned on the rig floor, wherein the first rig floor robot is configured to guide a lower end of a pipe stand towards a setback position on the rig floor and the second rig floor robot is configured to guide a first pipe joint of the pipe stand into a first mouse hole formed in the rig floor, a mast extending from the rig floor, a racking board coupled to the mast, the racking board configured to secure an upper end of the pipe stand between a pair of finger boards of the racking board, a racking board robot positioned on the racking board and configured to position the upper end of the pipe stand between the pair of finger boards.

Abstract: A hoisting system is for hoisting a vertically-suspended object. The hoisting system has a winch having a winch drum with a hoisting rope. A first part of the hoisting rope has a first diameter and a second part has a second diameter being larger than the first diameter. The first part is connected with a first end of the second part. The first part is an inner part on the winch drum when the winch drum is completely wound. The second part has a further end that is connectable to the object for hoisting the object. A ratio between the first diameter and the second diameter is such that the minimum breakable load of the first part differs less than a factor of four from the minimum breakable load of the second part, and preferably less than a factor of three. A corresponding method is disclosed.

Abstract: A flaw detection system may include a dedicated monitor volume within a structural component of a system. The monitor volume may establish an air tight space bounded by at least one joint where the joint establishes a portion of a boundary of the air tight space and is in fluid communication with the air tight space. The system may also include a pressure sensing device configured for sensing the pressure in the dedicated monitor volume. A method of monitoring a system for flaw development may include monitoring a pressure sensor configured to sense the pressure in a dedicated monitor volume of a structural component of a system. The method may also include inspecting the structural component to identify a flaw location when the pressure sensor identifies a change in pressure in the dedicated monitor volume.

Abstract: An assembly comprising an end-fitting and an unbonded flexible pipe comprising several layers. The unbonded flexible pipe has an end-part entering the end-fitting at the front end and the layers of the unbonded flexible pipe being terminated in the end-fitting. The unbonded flexible pipe further comprises a first electrically conductive layer and a second electrically conductive layer, where the first electrically conductive layer is electrically insulated from the second electrically conductive layer. The end-fitting comprises a first electric zone electrically connected with the first electrically conductive layer, and a second electric zone electrically connected with the second electrically conductive layer, the first electric zone is electrically separated from the second electric zone, and the end-fitting comprises a third electric zone, the third electric zone being electrically separated from first electric zone and the second electric zone.

Abstract: A method for drilling a borehole includes selecting a lower pressure limit and an upper pressure limit for a drilling fluid at a drilling location in the borehole. In addition, the method includes activating a pump to circulate the drilling fluid down a drill string and up an annulus disposed about the drill string. Further, the method includes operating the pump to maintain the drilling fluid at the drilling location at a pressure between the upper and the lower pressure limits. Still further, the method includes deactivating the pump to stop circulating the drilling fluid up the annulus. The method also includes sealing the drilling fluid in the annulus at a selected time after deactivating the pump and maintaining the pressure of the drilling fluid at the drilling location between the lower and the upper pressure limits.

Abstract: A system and method for recovering drilling fluid from shaker tailings includes a hopper and a cover that is pivotable between a first position in which the hopper is uncovered and a second position in which the hopper is covered. In the first position, the hopper receives the tailings, which are pumped via a low shear pump to a centrifuge. The drilling fluid extracted in the centrifuge is stored in a holding tank. In the second position, the cover is angled with respect to the direction of gravity so as to divert shaker tailings from being received in the hopper. Some fluid from the holding tank is sprayed into the hopper through nozzles to convey the deposited tailings toward the pump. A level detector senses the level of the mixture in the hopper, and an associated control system controls the pump speed and the cover position to control the operation.

Abstract: Some embodiments disclosed herein are directed to a tubular member including a central axis, a first end, a second end opposite the first end, an upset region between and axially spaced from the first end and the second end, and a first outer diameter axially spaced midway between the first end and the upset region. The upset region includes a second diameter which is larger than the first diameter, does not include a weld joint, and includes redistributed material from the tubular member.

Abstract: A method for increasing an amplitude of reciprocal axial extensions and contractions of a shock tool configured to induce axial oscillations in a drillstring during drilling operations includes (a) selecting the shock tool. The shock tool has a central axis and an axial length. The shock tool includes an outer housing, a mandrel telescopically disposed within the outer housing, and a first annular piston fixably coupled to the mandrel. The shock tool has a first amplitude of reciprocal axial extension and contraction at a pressure differential between a first fluid pressure in the outer housing and a second fluid pressure outside the outer housing. In addition, the method includes (b) fixably coupling a second annular piston to the mandrel of the shock tool and increasing the axial length of the shock tool after (a). The second annular piston is axially spaced from the first annular piston.

Abstract: A sheave assembly for use in a handling system or tensioning system, the sheave assembly having one or more sheaves arranged about a shaft and cone sub-assembly. The shaft and cone sub-assembly may include one or more pairs of bearing cones configured to interface with a plurality of bearing rollers to facilitate rotation of the one or more sheaves about the shaft and cone sub-assembly. The shaft and cone sub-assembly may be configured to be arranged in a fixed rotational position during handling or tensioning operations. The shaft and cone sub-assembly may further be configured to be rotated or repositioned about a central, longitudinal axis of the sub-assembly. The shaft and cone sub-assembly may be configured to rotate independent of the sheave(s) so as to reposition the one or more pairs of cones with respect to applied loading on the sheave assembly from the handling or tensioning operations.

Abstract: A system includes a string disposed in a wellbore, a first valve coupled to the string, the first valve including a sleeve having an engagement profile with a first coded sequence, a second valve coupled to the string, the second valve including a sleeve having an engagement profile with a second coded sequence that differs from the first coded sequence of the first valve, and a first dart flow transportable through the string, the first dart including a collet finger having a first coded sequence configured to restrict the collet finger from matingly engaging the engagement profile of the first valve while permitting the collet finger to engage the engagement profile of the second valve, wherein the first dart actuates the sleeve of the second valve between first and second positions in response to the collet finger of the first dart matingly engaging the engagement profile of the second valve.

Abstract: An insert for a drill bit includes a base portion. In addition, the insert includes a formation engaging portion extending from the base portion. The formation engaging portion has a longitudinal axis and includes a first end, a second end opposite the first end, a first lateral side extending from the first end to the second end, and a second lateral side extending from the first end to the second end, and an elongate crown extending longitudinally from the first end to the second end and laterally from the first lateral side to the second lateral side. The first lateral side comprises a first curved surface having a first radius of curvature in top view of the insert and the second lateral side includes a second curved surface having a second radius of curvature in top view of the insert. The first radius of curvature of the first curved surface is different than the second radius of curvature of the second curved surface.

Abstract: A pipe handling system for handling drill pipe on a drill rig may include a lifting system configured for handling a load of a pipe stand and a first pipe handling robot arranged at or near a drill floor of the drill rig and configured for manipulating a bottom end of the pipe stand between a setback area on the drill floor and well center. The system may also include a second pipe handling robot arranged at or near a racking board of the drill rig and configured for manipulating a top end of the pipe stand between the racking board and well center. The first pipe handling robot may have a base that is supported from a location outside a plan view envelope of the setback area of the drill floor.

Abstract: A cutter element for a drill bit includes a base portion having a central axis, a first end, a second end, and a radially outer surface extending axially from the first end to the second end. In addition, the cutter element includes a cutting layer fixably mounted to the first end of the base portion. The cutting layer includes a cutting face distal the base portion and a radially outer surface extending axially from the cutting face to the radially outer surface of the base portion. The cutting face includes a planar central region centered relative to the central axis and disposed in a plane oriented perpendicular to the central axis. Further, the cutting face includes a plurality of circumferentially-spaced cutting regions disposed about the planar central region. Still further, the cutting face includes a plurality of circumferentially-spaced relief regions disposed about the planar central region.

Abstract: A sliding sleeve valve for use in a borehole includes an outer housing including a radial housing slot, a sliding sleeve slidably disposed in the outer housing, the sliding sleeve including a radial sleeve slot and configured to have a first position that restricts fluid communication between the sleeve slot and the housing slot and a second position, spaced from the first position, that permits fluid communication between the sleeve slot and the housing slot, an actuator housing coupled to the outer housing, wherein the actuator housing includes an actuator chamber defined by an inner surface, and wherein the actuator chamber is disposed between an inner surface and an outer surface of the actuator housing, and an actuator assembly disposed in the actuator chamber, wherein the actuator assembly is configured to control movement of the sliding sleeve between the first and second positions.

Abstract: A rope connector connects prepared ends of two rope segments, wherein said prepared ends each include a rope eye. The rope connector includes at least two complementary parts, each being configured with a shaped recess for receiving at least part of said prepared end of a respective rope segment. The complementary parts are detachably mountable to each other to establish a firm connection there between. A rope extension system is disclosed to include such rope connector, and a hoisting system employs such rope extension system.

Abstract: Power generation assemblies and methods relating thereto are disclosed. In an embodiment, the power generation assembly includes a thermoelectric generator, and a conductor configured to conduct electricity generated by the thermoelectric generator to the surface of a subterranean wellbore. The power generation assembly is to circulate a working fluid through a closed loop in the power generation assembly in response to the receipt of geothermal energy within a subterranean formation, to cause the thermoelectric generator to generate electricity.

Abstract: An unbonded flexible pipe with a length and bore and an offshore installation are disclosed. The pipe comprises an internal pressure sheath, at least one metallic armouring layer surrounding the internal pressure sheath and at least one additional layer surrounding the metallic armouring layer. The metallic armouring layer comprises helically wound armouring elements which are at least partly covered by a viscous fluid having a kinematic viscosity of at least about 1000 cSt (ASTM D445 or ASTM D2170). The at least one additional layer surrounding the metallic armouring layer provides a gas escape route radially outwards from the metallic armouring layer beyond an outermost layer of the least one additional layer or to a lengthwise gas escape path in or between the at least one additional layer.

Abstract: Pump assemblies, pumping systems including said pump assemblies, and related methods are disclosed. In an embodiment, the pump assembly includes a frame, a fluid end, and a power end coupled to the frame and the fluid end. In addition, the pump assembly includes a plurality of connectors coupled between the fluid end and the frame. Each of the connectors include an axis, a first connector member, and a second connector member. The first connector member is configured to actuate relative to the second connector member to adjust a total axial length of the connector along the axis.

Abstract: A bend adjustment assembly for a downhole mud motor includes a driveshaft housing, a driveshaft rotatably disposed in the driveshaft housing, a bearing mandrel coupled to the driveshaft, wherein the bend adjustment assembly includes a first position that provides a first deflection angle between a longitudinal axis of the driveshaft housing and a longitudinal axis of the bearing mandrel, a second position that provides a second deflection angle, and a third position that provides a third deflection angle, and an actuator assembly configured to shift the bend adjustment assembly between the first position, the second position, and the third position in response to a change in at least one of flowrate of a drilling fluid supplied to the downhole mud motor, pressure of the drilling fluid supplied to the downhole mud motor, and relative rotation between the driveshaft housing and the bearing mandrel.