Abstract: An apparatus and method for assigning drill holes. The apparatus is arranged to determine a forthcoming position of a bottom of a new drill hole before it is drilled. The forthcoming position of the drill hole bottom is determined on the basis of the current location and direction of a tool and a planned length of the drill hole.

Abstract: A downhole component including a first portion; a second portion; a controlled failure structure between the first portion and second portion. A method for improving efficiency in downhole components.

Abstract: A cutter for a boring head having a shaft is mountable at a saddle. A roller body is rotatably mounted about the shaft via bearings housed at a cavity located radially between the shaft and the roller body. A lubrication fluid is configured to flow internally within the shaft via a first and second passageway. An elongate overflow chamber is provided in fluid communication with the passageways to receive thermally expanded lubrication fluid from the cavity.

Abstract: A subterranean support-bolt drill bit has a bit body rotatable about a central axis, the bit body having a forward end and a rearward end axially spaced away from the forward end. The support-bolt drill bit includes at least one bit cutting element coupled to the bit body, the at least one bit cutting element including a cutting edge. The support-bolt drill bit also includes a central pilot projecting from the bit body beyond the at least one bit cutting element in an axially forward direction, the central pilot including a pilot cutting edge.

Abstract: An earth-boring tool includes a body, blades extending longitudinally and generally radially from the body, and cutting elements located on each blade. The earth-boring tool may also include a first group of at least two adjacent blades comprising the cutting elements proximate a front cutting edge of the blades and one or more shaped inserts located rotationally following the cutting elements, and a second group of one or more additional blades comprising the cutting elements proximate the front cutting edge of the blades while being entirely free of the one or more shaped inserts. Methods include drilling a subterranean formation including engaging a formation with the cutting elements and the shaped inserts of the earth-boring tool, the shaped inserts secured at selected locations on two or more adjacent blades of the first group of blades while the second group of blades is entirely free of the shaped inserts.

Abstract: A cutting insert for milling wellbore casing in a downhole environment includes a body having a cutting face and a chip-breaking face. The cutting face and chip-breaking face are oriented at a face angle relative to each other, the face angle being between 75° and 130°. As the wellbore casing is milled, swarf is formed and work hardened. Further deformation of the swarf and movement along, or in contact with, the chip-breaking face breaks the swarf into chips that are readily flushed away or transported within the wellbore.

Abstract: The present invention relates to a marine drilling riser joint, adapted for the securement of one or more umbilicals (36) thereto. The marine drilling riser joint comprises one or more umbilical gutter assemblies (8), connected to or formed integral in an outer surface of a buoyancy module on the exterior of the marine drilling riser joint and provided parallel to the riser pipe, the umbilical gutter assembly comprising: an umbilical gutter (8) adapted to accommodate one or more umbilicals; and a resilient gutter cover (82a, 82b), which is elastically deformable by a loom tool, which resilient gutter cover in a closed position covers the umbilical gutter and in an elastically deformed position provides a working clearance to allow the one or more umbilicals to be introduced into the umbilical gutter.

Abstract: Disclosed are systems and method of securing and protecting control lines during run-in into a wellbore with wellbore tape. The wellbore tape includes a substrate having a front surface and a back surface, a wear-resistant coating disposed on at least a portion of the front surface, and an adhesive layer disposed on the back surface, the adhesive layer being configured to affix the substrate to an outer surface of a conveyance.

Abstract: A drill string comprising a bit portion, a distal extension portion, a proximal extension portion, and a connecting portion. The bit portion is operatively connected to the distal extension portion and the connecting portion operatively connects the distal extension portion to the proximal extension portion to define supply path and a return path. The supply path extends through the distal proximal extension portion, the connecting portion, the distal extension portion, and the bit portion to a cutter region associated with the bit portion. The return path extends from the cutter region through the bit portion, the distal extension portion, the connector portion, and the proximal extension portion.

Abstract: A pressure control device can include an outlet, an inlet secured to well equipment, and a swivel mechanism that permits relative rotation between the outlet and the inlet in an unlocked configuration and prevents relative rotation between the outlet and the inlet in a locked configuration. A lock device of the swivel mechanism can include circumferentially distributed teeth, and an engagement member that engages at least one of the teeth in the locked configuration. A method of operating a pressure control device can include securing an inlet of the pressure control device to well equipment, rotating an outlet of the pressure control device about a longitudinal axis of the inlet, locking a swivel mechanism of the pressure control device, thereby preventing rotation of the outlet relative to the inlet, and sealing off an annulus surrounding a tubular string extending through the inlet.

Abstract: A seal stem anchor assembly of the present disclosure includes: a tubular portion having body lock threads disposed about an external portion; and an anchor assembly including an activation module about the tubular portion and proximate the body lock threads, a cone, one or more anchor slips extending between the activation module and the cone, and a helical spring positioned and biased so as to push the activation module away from the cone.

Abstract: A sub assembly for coupling to a drill string, the assembly comprising; a mandrel; a sleeve arranged to be co-axially positioned about said mandrel; a first stop arranged to prevent axial movement of the sleeve along the mandrel in a first direction; a second stop arranged to prevent axial movement of the sleeve in a second direction; wherein said second stop is releasably engageable from the mandrel.

Abstract: The present disclosure relates to a gripper assembly for handling continuous rod. The gripper assembly may include a gripper face with a gripper profile forming a surface in the gripper face and a texture on a portion of the surface. The texture has a plurality of ridges having a yield strength sufficient to transfer a shear force to the gripper assembly at least as large as a weight of a continuous rod.

Abstract: The present disclosure generally relates to elevators and other tools having radio frequency identification (RFID) tags embedded therein to facilitate identification of the elevators. The tools include an RFID tag embedded therein to facilitate identification of the tool. The RFID tag may be disposed in a bore formed in tool, and then optionally covered with a capping material.

Abstract: A chuck for a drill head of a rotation rock drilling rig, wherein a plurality of jaws are equally angularly distributed around a grip position axis, wherein the jaws co-operate with actuator means for radial movements of the jaws, and wherein the chuck includes urging means being arranged for influencing the jaws into the release position. The urging means is a partially annular jaw spring surrounding said axis and having two spring ends adjacent to each other. The jaws together form an inside seat for the jaw spring and the jaw spring is arranged for fixing engagement with one of the jaws. The invention also relates to a drill head, a rig and a jaw spring.

Abstract: A control system for actuating a drill pipe rack is provided. The drill pipe rack moves between a first position and a second position. The control system includes a first actuator to actuate a top end of the drill pipe rack and a second actuator to actuate a bottom end of the drill pipe rack. The control system includes a pump to supply pressurized fluid to the first actuator and the second actuator. The control system further includes at least one volumetric flow divider in fluid communication with the pump. The volumetric flow divider is configured to supply equal volumetric quantity of the pressurized fluid to the first actuator and the second actuator, and subsequently move the drill pipe rack between the first position and the second position.

Abstract: The present disclosure generally relates to a tong assembly for making up and breaking out a tubular connection such as a connection between two tubulars in a tubular string. The tong assembly includes a power tong, a backup tong and a load transfer assembly connected between the power tong and the backup tong. The load transfer assembly comprises a torque bar and one or more sensors to measure a torque exerted on the torque bar. The torque measurements of the torque bar may be used to monitor the torque exerted on the tubular string by the tong assembly.

Abstract: A coiled tubing conveyance apparatus includes a tubing injector and a guide roller frame having a coiled tubing reel attached thereto movably mounted on the tubing injector. The guide roller frame includes at least one guide roller to straighten a coiled tubing extended from the coiled tubing reel. A transverse motion apparatus is coupled to the tubing injector and the guide roller frame such that the guide roller frame is movable transversely with respect to a direction of motion of coiled tubing through the tubing injector.

Abstract: A filtration and testing device integral thereon, for simultaneously performing cleaning of fluid used in the oil and natural gas industry for completions, workovers, and commissioning of wells while simultaneously pressure testing of two separate groups of pressurized equipment using fluid cleaned by the filtration and testing device. A support structure has a cleaning cycle assembly and a pressure testing cycle assembly connected in parallel to a controller for cleaning fluid and regulating pressure by comparing fluid pressures to preset limits. The controller regulates cleaning of first and second dirty hydraulic fluids and regulates pressure of cleaned hydraulic fluids and secondary fluids for pressure testing of the two different groups of pressurized equipment simultaneously.

Abstract: A technique facilitates monitoring of flow conditions with respect to flow through a tubing. A distributed sensor is routed along an interior of the tubing to monitor flow conditions. For example, the distributed sensor may be routed over a length of the tubing having a lateral opening. Fluid is flowed along the distributed sensor and within the interior of the tubing. The distributed sensor is operated to measure strain which results from flow of the fluid along the distributed sensor. The strain may then be evaluated to determine a change in a flow condition, such as a change in a flow condition related to the lateral opening.

Abstract: Various tools for locking components in place within a wellhead housing are provided. In one embodiment, a system includes a lockdown tool (32) having an inner body (40), an outer body (42) coupled to the inner body, and a locking mechanism (44) carried by the inner body. The locking mechanism can be selectively engaged by moving the outer body with respect to the inner body to secure the lockdown tool to the wellhead housing (60). Additional systems, devices, and methods are also disclosed.

Abstract: Wall openings in a mandrel of a liner hanger/packer are eliminated and setting is accomplished with pressure against a landed object in a running tool. The wall of the running tool leads to a sealed annular space with a movable seal attached to a setting sleeve and the other end is a packer cup supported by the running tool. The setting sleeve sequentially sets the slips and releases the running tool followed by setting the packer seal. Optionally a dog sub can be used to set with set down weight on the setting sleeve. The set positions are locked in. The slips can be alternatively set with release of a contained spring force. The setting sleeve seal can be sheared out to allow removal of the running tool.

Abstract: A method of plugging a well extending into a formation to facilitate temporary or permanent abandonment of the well. The method comprises conveying in one trip, a plug assembly and one or more explosive charges through the well together with a structure for providing wet sealant. The plug assembly comprises a foundation plug for supporting the wet sealant. The plug assembly is set beneath a plug formation location, prior to providing the wet sealant. The method also comprises providing the wet sealant to the plug formation location via the structure, so as to submerge the one or more explosive charges in the wet sealant, and then detonating the one or more explosive charges in the wet sealant at the plug formation location to cut through a tubular or tubulars of the well and into the formation.

Abstract: “SECURITY MECHANISM FOR INSTALLATION IN SOIL DRILLING TOOLS, WITH GAS/OIL LEAKAGE LOCKING SYSTEM ON RECOVERY STAGE OF INTERNAL TUBE CONTAINING TOKEN”, where a mechanism for installation on drilling equipment tooling (which uses barrel for the continuous token extraction), be developed with a cable gland assembly (1), connectors (22), (32) and valve (42). With such elements, the mechanism offers a sealing system that prevents, in the recovery step of the inner tube with the token, that there is oil or gas leakages. The mechanism also has an additional safety device (52). Thus, the tooling typically used for ore survey (simpler and cheaper) may be used in wells for gas/oil drilling, bringing remarkable benefits in the segment, both in operationally and commercial level.

Abstract: Payload container and system for delivering a payload to a wellbore, the payload container includes a blister container having a cavity formed therein and an edge about the perimeter of the cavity, one or more payload substances contained within the cavity, a lidding material to cover the cavity, and optionally, an adhesive to bond the lidding material to the edge of the cavity, so that the one or more payload substances can be released in response to an external stimulus. The wellbore payload delivery system includes a plurality of payload containers and a pump system for injecting the one or more payload containers into a wellbore, the pump system has a pump and a length of tubing coupled with the pump and extending to a zone of a subterranean formation adjacent to the wellbore.

Abstract: Apparatus and adapter are usable for aligning downhole torch apparatuses and cutting devices, including axial pyro torches, circulating pyro torches, and radial cutting and perforating torches, within a wellbore for removal of one or more downhole obstructions. The torch and/or cutting apparatus comprises a body having a nozzle adapted to project a fuel load, such as molten thermite or molten thermite with a polymer, in a direction aligned with the obstruction. The adapter comprises protruding elements for eliminating or diminishing damage to the area surrounding the obstruction, including the inner walls of the wellbore and/or casing, and can further comprise centralizers for alignment of the apparatus with the obstruction, within the wellbore.

Abstract: A cable grab assembly includes a body having a longitudinally extending internal cavity disposed therein. A piston is disposed in the cavity and is axially moveable between a first position and a second position. At least two grab arms are hingedly attached to a bottom end of the body. A linkage assembly operatively couples the piston and the at least two grab arms such that movement of the piston between the first position toward the second position causes the at least two grab arms to pivot inward from an open position toward a closed position. A shear-pin restrains the piston to the first position. At least one spring element is disposed between the piston and an end of the cavity to shift the piston from the first position toward the second position to capture a broken cable when the shear-pin is sheared.

Abstract: This disclosure includes auxiliary-line riser segment assemblies (e.g., with isolation units) that are suitable for managed pressure drilling (MPD) and that can be lowered (e.g., when connected to other riser segment assemblies) through a rotary of a drilling rig. Some embodiments are configured to have portions of the auxiliary lines connected (e.g., without welding) below the rotary.

Abstract: An improved top pot assembly utilizes an attachment body for attaching the rubber to a bearing assembly for rotation with the inner barrel. The attachment body simplifies the replacement of the rubber on the drilling assembly. The attachment body provides a guide that slopes downward into the central aperture and the bore to guide the mandrel and drilling string towards the bore. The attachment body also provides a stripper receiver for attachment of the rubber to the attachment body. The attachment body attaches to the housing which attaches to the bearing assembly for rotation of the rubber and the inner barrel.

Abstract: A method and apparatus for transporting a capping stack for use in a subsea structure includes a capping stack having a capping stack spool, a connector body connectable to the capping stack spool and at least one diverter leg connectable to the capping stack spool. A first skid receives the capping stack spool on a floor thereof. A second skid receives the connector body on a floor thereof. A third skid receives the diverter leg thereon. The first, second and third skids are adapted to be received within an interior of an aircraft. The skids and the connected components can then be flown by the aircraft to a desired location so as to be assembled at a location near a wellhead.

Abstract: A lubricator system according to which a lubricator defines an internal passage that extends along a curvilinear path. The lubricator is configured to be connected to a wellhead at the top or head of an oil and gas wellbore. A downhole tool is configured to be conveyed through the internal passage of the lubricator and along the curvilinear path in combination with a conveyance string connected to the downhole tool. The downhole tool may be, include, or be part of, for example, a perforating gun.

Abstract: A method for conducting well intervention operations includes disposing a combination well intervention apparatus proximate a pressure control apparatus coupled to the wellbore. The apparatus has a pressure control device adapter and at least one other type of well intervention device coupled to the adapter such that either the adapter or the at least one other apparatus is disposed over the pressure control apparatus. The method includes at least one of, (i) locking the adapter in the pressure control apparatus by operating a remotely operable locking device on the pressure control apparatus or (ii) disposing the other type of well intervention device over the pressure control apparatus. The method includes locking the adapter in the pressure control apparatus when the adapter is disposed over the pressure control apparatus, or operating the at least one other type of well intervention device when disposed over the pressure control apparatus.

Abstract: The fluid containment system attaches to the wellhead below the rotating control device to catch fluids. The fluid containment system provides a pan below the outlet of the body in which the rotating head assembly is secured. A curtain attaches to the fluid containment system to at least partially enclose the wellhead. The curtain directs the escaped fluids to the pan. An opening in the curtain provides an outlet for the body allowing fluids within the pipe to flow from the body. Conduits attach to outlets of the pan to transfer the fluids from the pan to a tank.

Abstract: The plug includes a rigid tapering frustum with an upstream end having a larger diameter than a downstream end. A bladder is located outboard of the frustum and preferably fastened to the frustum. The bladder preferably has a toroidal form. A fluid fill system extends into an interior of the bladder to provide fluid for inflating or deflating the bladder. When the bladder is inflated with fluid passing into the interior, an outer wall of the bladder is expanded against a wall of a pipe where the plug is located, to hold the plug in place. As pipeline fluid forces act downstream on the frustum of the plug, the frustum moves slightly downstream, exerting a radial force through the bladder and against the wall of the pipe, so that pressure within the pipe and upstream of the plug enhances radial force with which the bladder engages the pipe wall.

Abstract: A borehole plug or packer for treating is designed to be flowed back to a surface location after use. When the treatment is concluded pressure from above is relieved or lowered, and well fluid is flowed back, so that the plug or plugs disengages at slips designed to resist differential pressure from above. The application of differential pressure from below causes the lower slips to release one or more of such plugs in the hole into specialized sub surface or surface capture equipment so that well pressure is relieved before removal of the plugs from specialized subsurface or surface capture equipment.

Abstract: A crossover tool for use in a wellbore includes: a tubular housing having a bypass port; a mandrel having a bore therethrough and a mandrel port in fluid communication with the mandrel bore, the mandrel movable relative to the tubular housing between a first position where the mandrel port is isolated from the bypass port and a second position where the mandrel port is aligned with the bypass port; and an actuator operable to move the mandrel between the first position and the second position. The actuator includes a first piston connected to the mandrel and a second piston operable in response to the first piston.

Abstract: A downhole tool is responsive to passing objects and applied fluid pressure. A plugless valve in the tool is operable from an unobstructed condition to an obstructed condition unobstructing the tool's bore to an obstructed condition obstructing the tool's bore to the applied fluid pressure. An indexer counts the objects passing through the tool's bore and permits operation of the plugless valve from the unobstructed to the obstructed condition in response to the counted number. The applied fluid pressure in the bore obstructed by the plugless valve can then communicate outside the tool via at least one port. The plugless valve can have a movable insert that moves relative to a flapper. The indexer can use ratcheting dogs, collet, J-slot, electronic sensor, and other components to count the passing objects.

Abstract: A technique facilitates mechanical operation of components, e.g. valves, without utilizing electronics at the components or control lines routed to the components. An actuation control system is fully mechanical in the sense that it is constructed to mechanically shift to different control positions via pressure input, such as pressure input supplied along a wellbore annulus. The actuation control system utilizes a spool valve coupled with a pilot control circuit which establishes a reference pressure that can be used in shifting the spool valve to different operational positions.

Abstract: A downhole tool (1) method and device, in which the downhole tool (1) is designed to form part of a pipe string (4), and in which a valve (24) is provided with a passage (120) for fluid, the passage (120) including an opening and closing mechanism (78), and the method including: connecting a first valve portion (26) to the pipe string (4); connecting a second valve portion (28) telescopic relative to the first valve portion (26) to a downhole object (20); pre-tensioning the first valve portion (26) and the second valve portion (28) in the direction of contraction to an initial position, in which the opening and closing mechanism (78) is open; and moving the first valve portion (26) relative to the second valve portion (28) in the direction of extension to close the opening and closing mechanism (78).

Abstract: A technique facilitates the anchoring and use of a downhole tool. The technique may be utilized with operations in which fluid is pumped or otherwise flowed through a tubular to the downhole tool. The operations are performed after the downhole tool has been fixed relative to the wellbore and while the tubular remains connected to the downhole tool. In some operations, the downhole tool is manipulated from the surface via the tubular to control placement of the fluid flowing down through the tubular.

Abstract: Copolymers containing acryloylmorpholine and vinylimidazole, and optionally vinylcaprolactam and/or n-vinyl pyrrolidone, have shown superior results in hydrate inhibition tests at conditions of 7° C. subcooling dosed at 1 vol % based on the water cut of the system fluids. The copolymer product has also passed high TDS (total dissolved solids) brine compatibility tests and secondary property tests including foaming and hot injection tests which make it useful as a kinetic hydrate inhibitor in gas production systems susceptible to the formation of natural gas hydrates.

Abstract: A technique facilitates creation of and production from a multilateral well. A lateral junction is deployed downhole to a lateral bore via a conveyance, such as a coiled tubing conveyance. The lateral junction comprises a main bore tubular and a lateral bore tubular which are pivotably joined via a pivotable coupling. The pivotable coupling enables pivoting of the lateral bore tubular outwardly through a lateral opening of the main bore tubular. The construction of the lateral junction enables establishment of a lateral junction, such as a TAML Level 3 or TAML Level 4 junction, in a single trip downhole.

Abstract: The disclosed embodiments include a computer implemented method, apparatus, and computer program product that includes executable instructions that when executed performs operations for determining flow control device properties for an injection well that would yield to a prescribed uniform or non-uniform accumulated injection profile along a production well.

Abstract: Method of stopping and restarting production in an undersea bottom-to-surface connection production pipe having a first pipe portion on the sea bottom from a well head to the bottom end of a second pipe portion extending to a ship or floating. When production is stopped, at least the first pipe portion is filled with a depressurized production fluid. Thereafter the following steps are performed: e1) forming a gel from two reagents in a first gel-forming chamber on the sea bottom; e2) sending a quantity of separator gel into the first pipe portion that pushes the cold fluid contained in the first pipe portion to the second pipe portion, prior to closing the first chamber; and then; e3) starting production, the gel forming physical separation and thermal and chemical isolation between firstly the production fluid and secondly a production fluid within the first production pipe portion.

Abstract: In accordance with the present disclosure, a full top-to-bottom subsea system and method used to drill, complete, produce, and perform interventions on HPHT subsea wells is provided. The disclosed systems and methods involve the use of a controlled multiple barrier system, such as a high integrity pipeline protection system (HIPPS), incorporated into the subsea system to divide the system into two sections. The sections on either side of the barrier may be rated for different pressures, temperatures, and/or flow rates. For example, the first section (upstream of the barrier) is rated for operating at pressures/temperatures/flow rates up to a first (higher) threshold. The second section (downstream of the barrier) is rated for operating at pressures/temperatures/flow rates up to a second (lower) threshold. The disclosed subsea production system methodology, which uses barriers to divide the system components between two pressure ratings, may allow for enhanced development of HPHT reservoirs.

Abstract: A method of producing hydrocarbon from a subterranean formation comprises: disposing an article in a well penetrating a subterranean formation, the article having a surface coated with a hierarchical superhydrophobic coating or the article being a stand-alone hierarchical superhydrophobic membrane; contacting the article with a flow of a water-based fluid and an oil-based fluid; selectively impeding the flow of the water-based fluid; and allowing the production of the oil-based fluid.

Abstract: A device for perforating a well-casing. The device includes a body that has a passageway defined in it. The passageway has a first portion and a second portion. The body is configured to transition from a first condition to a second condition. When the body is in the first condition, the first portion of the passageway is not fluidly connected to the second portion passageway. When the body is in the second condition, the first portion of the passageway is fluidly connected via the second portion of the passageway to an exterior surface of the well casing.

Abstract: Sliding sleeve assemblies including a completion body with an inner flow passageway and one or more ports enabling fluid communication between the inner flow passageway and an exterior of the completion body. A sliding sleeve is arranged within the completion body and has a sleeve mating profile defined on an inner surface, the sliding sleeve being movable between a closed position, where the one or more ports are occluded, and an open position, where the one or more ports are exposed. A plurality of wellbore darts are used and each has a body and a common dart profile that is matable with the sleeve mating profile. One or more sensors are positioned on the completion body to detect the plurality of wellbore darts traversing the inner flow passageway. An actuation sleeve is arranged within the completion body and movable to expose the sleeve mating profile.

Abstract: A method for recovery of oil housed in a reservoir comprising injecting an aqueous solution or slurry of a carbonate salt into a wellbore and allowing the aqueous solution or slurry of the carbonate salt to enter into the reservoir. An aqueous solution of an acid is then injected into the wellbore and allowed to enter into the reservoir. The carbonate salt and the acid are allowed to react with each other and form carbon dioxide (CO2) gas, inside the reservoir, which mixes with the reservoir oil and thereby reduces the viscosity of the oil within the reservoir. The method also provides for a rapid effervescence of carbon dioxide that may enhance oil recovery by improving oil flow to the wellbore by increasing reservoir pressure, increasing rock permeability from sand production, causing oil swelling, inducing foamy oil creation and/or removing formation skin damage.

Abstract: Estimates of global total “liquid” hydrocarbon resources are dominated by structures known as oil sands or tar sands which represent approximately two-thirds of the total recoverable resources. This is despite that the Canadian Athabasca Oil Sands, which dominate these oil sand based recoverable oil reserves at 1.7 trillion barrels, are calculated at only a 10% recovery rate. However, irrespective of whether it is the 3.6 trillion barrels recoverable from the oil sands or the 1.75 trillion barrels from conventional oil reservoirs worldwide, it is evident that significant financial return and extension of the time oil as resource is available to the world arise from increasing the recoverable percentage of such resources. According to embodiments of the invention pressure differentials are exploited to advance production of wells, adjust the evolution of the depletion chambers formed laterally between laterally spaced wells to increase the oil recovery percentage, and provide recovery in deeper reservoirs.