БУРОВОЙ НАВЕС

Полезная модель относится к строительству, в частности к узлам бурильно-крановых машин с прерывистым вращением инструмента в одном направлении. Способствует снижению изгибающих нагрузок, действующих на подвес бурового вращателя.

УНИВЕРСАЛЬНЫЙ ШАРНИР ВЫСОКОЙ НАГРУЗКИ ДЛЯ СКВАЖИННОГО РОТОРНОГО УПРАВЛЯЕМОГО БУРОВОГО ИНСТРУМЕНТА

Изобретение относится к устройствам для направленного бурения. Техническим результатом является создание компактной системы бурения скважины, содержащей универсальный шарнир с высокой несущей способностью. Высокая несущая способность достигается методами, применяющими уникальные механизмы передачи нагрузки. Например, более высокая несущая способность может обеспечиваться с использованием принципа распределения нагрузки, согласно которому скручивающие напряжения передаются совместно через штифты универсального шарнира и боковые грани крестовины универсального шарнира. Более высокая несущая способность может также достигаться путем передачи нагрузки через монолитную крестовину, имеющую штифты, составляющие с ней единое целое, и блок разъемная вилка/хомут. В другом варианте воплощения более высокая несущая способность является результатом использования штифтов универсального шарнира, вставленных с внутренней стороны универсального шарнира и завинченных наружу до достижения полного соединения ...

СПОСОБ БУРЕНИЯ СТВОЛА СКВАЖИНЫ В ГРУНТЕ, ИМЕЮЩЕГО КРИВОЛИНЕЙНЫЙ УЧАСТОК С МАЛЫМ РАДИУСОМ КРИВИЗНЫ И ПРЯМОЛИНЕЙНЫЙ УЧАСТОК НА КОНЦЕ КРИВОЛИНЕЙНОГО УЧАСТКА, И БУРОВОЙ ИНСТРУМЕНТ ДЛЯ ЕГО ОСУЩЕСТВЛЕНИЯ

Предложены способ бурения участка ствола скважины, включающего криволинейный участок с малым радиусом кривизны, за которым следует прямолинейный участок, и буровой инструмент, имеющий первую часть, на которой смонтирована буровая коронка, и вторую часть, несущую электродвигатель, с шарнирным соединением между ними. Образование криволинейного участка с малым радиусом кривизны завершают, используя буровой инструмент с шарнирным соединением, отклоняющимся к первой стороне ствола для направления буровой коронки к другой стороне. После завершения образования криволинейного участка выполняют бурение в строго прямолинейном направлении путем установки эксцентрической муфты, которая крепится на буровом инструменте рядом с шарнирным звеном. Эксцентрическая муфта удерживает буровой инструмент под углом, меньшим, чем угол при бурении криволинейного участка. Одновременно с вращением буровой коронки буровой став, инструмент и муфта вращаются более медленно вокруг продольной оси с тем, чтобы постоянно ...

Device for laying pipes below ground

The device has an expansion head (2), a swivelling element (3), a force-locking coupling element and an inner draw head (6). The swivelling element can move axially and is replaceably mounted inside the expanding head. When a thrust force is applied the inner draw head comes into contact with the expanding head. When the inner draw head comes into contact with the expanding head under the action of the thrust force, a tube (7) coupled to the inner draw head via a yoke bridge (5) is guided into a bore without lateral deviation.

Wellbore apparatus and method

Method and apparatus for orienting perforating devices

Improved Swivel for use in Well-drilling.

... 111,253. Growder, J. June 19, 1917. Bore-hole apparatus. - A swivel for use in well drilling comprises a body part b to which the tool is secured and which contains a chamber d with a lateral opening o through which may be inserted the tubular shouldered spindle e connected to the operating rope. A cross pin p may then be fixed below the spindle. A washer g is provided above the shoulder on the spindle, and flats r may be provided on the washer and spindle so that the width of the slot o may be kept small. Grooves s are provided for the engagement of fishing-tools.

Tension-set tieback packer

An apparatus 50 for supporting tubing in casing, such as a liner hanger, includes a packer 200 and setting tool 100, having inner mandrel 102 and outer mandrel 101. Setting slips 212a-b are movable from a retracted to an extended state engaging the casing. In use, the inner mandrel may be first rotated with respect to the outer mandrel to permit extension of the slips, before then being moved with a first movement relative to the outer mandrel to compress the packing element. The inner mandrel is then rotated a second time with respect to the outer mandrel to disengage or release the setting tool from the deployed packer. There may be an initial movement between the inner and outer mandrels after the first rotation to drive the slips into engagement with the surrounding tubular.

UNIVERSAL JOINT ARRANGEMENT FOR DOWNHOLE TOOLS

A universal joint arrangement includes a first adapter 11 having two projecting support formations 14, 15, a drive plate 20 having a first pair of matching depressions or pockets 24, 25 is seated with these depressions on the projecting support formations of the first adapter and the drive plate has a second pair of pockets 29, 30 for the projecting support formations of a respective second adapter 33. The joint arrangement is particularly used in the drive transmission of a MOYNO motor of an oil well where the joint compensates for the eccentric motion of the MOYNO motor. …… ...

Drilling apparatus and swivel device thereof

Downhole clutch assembly

A downhole clutch assembly, for use in a wellbore, comprising an elongate drive shaft 502 and an elongate driven shaft 504, each shaft having a longitudinally extending bore 506 and 508, for providing fluid communication between the two shafts, and coupling means 514 and 516 for coupling the drive shaft, to the driven shaft. The coupling means being such that, the driven shaft will only rotate with the drive shaft in one direction, of drive shaft rotation. The coupling means may comprise an axially movable collar 510, with a plurality of detentes (Fig 5C, 514), on one of the shafts, which is biased into engagement with a plurality of detentes (Fig 5C, 516), on the other shaft. The detentes may be angled, relative to one another, such that in one rotation direction, the detentes ride over each other, compressing the biasing means, and disengaging the two shafts, while in the other rotation direction, the detentes are locked together, allowing the drive shaft to rotate the driven shaft.

A disconnection device for a wireline

Downhole swivel joint

Compression set downhole clutch

Compression set downhole clutch (100) can include an upper body (201), a lower body (202), and a hydraulic member (205). The upper body (201) can include at least one engagement surface (204). The lower body (202) can include at least one engagement surface (203). The at least one engagement surface (204) of the upper body (201) and the at least one engagement surface (203) of the lower body (202) can each be configured to couple with one another and rotate in unison in an engaged configuration (102). The hydraulic member (205) can be configured to be responsive to a predetermined pressure; the hydraulic member (205) can also be configured to disengage the engagement surface (204) of the upper body (201) from the engagement surface (203) of the lower body (202).

Compression set downhole clutch

Wellhead seal unit

A wellhead seal unit for sealing a subsea oil and/or gas well at the wellhead. The unit comprises a sleeve, sealingly engaged to the workstring and to which, blow out preventer rams can engage. The unit allows the workstring to be rotated and reciprocated within the wellbore without releasing the seal. Methods of cleaning the sealed well and performing an inflow test are described.

A bi-directional pressure energised axial seal and a swivel connection application

A tubular connection has first and second tubular members 11, 17 having aligned bores 19 with a common axis 21 and having first and second seal surfaces 29, 33, respectively. A metal seal 37 has a first end portion 41 that sealingly engages the first seal surface 29 and a second end portion 45 that sealingly engages the second seal surface 33. The metal seal 37 has a sidewall 47 with at least two folds 49, 51. One of the folds 49 defines an axial interior gap. The other of the folds 51 defines an axial exterior gap. An exterior spacer member 61 is positioned in the exterior gap to limit closing of the exterior gap in response to a greater pressure on the interior of the seal 37 than on the exterior. An interior spacer member 55 is positioned in the interior gap to limit closure of the interior gap in response to a greater pressure on the exterior of the seal 37 than on the interior.

Downhole swivel sub

Articulated universal joint with backlash reduction

A universal joint includes a joint housing and a joint shaft. The joint housing includes a socket having one or more recesses. The joint shaft includes a head positioned in the socket of the joint housing. The head includes one or more lobes corresponding with the recesses of the socket. The universal joint includes a drive key positioned between each lobe drive face and each recess drive face and an anti-backlash key positioned between each lobe back face and each recess back face.

Wellhead seal unit

Downhole swivel tool

Swivel joints for conduits

... 1,067,997. Rotary joints; bearings. FMC CORPORATION. Aug. 4, 1964 [July 29, 1963], No. 22817/66. Divided out of 1,067.996. Headings F2A and F2G. A swivel joint for conduits comprises a coupling member 11 having a cylindrical outer surface provided with an annular raceway 16, an annular outer bearing 50 including a pair of interchangeable portions 52, 54 circumscribing the member and having an outer raceway 62. ball members 85 engaging in the raceways, and a coupling member 20, and means extending through and connecting the bearing to the member 20. The coupling is fully described in the parent Specification.

Load-bearing universal joint with self-energizing seals for a rotary steerable drilling tool

A rotary steerable drilling tool and a method according to which a universal joint is sealed. In one embodiment, the method includes providing the collar, the shaft, the universal joint, and first and second shoulders between which the universal joint is positioned; providing first and second self-energizing seals between the collar and the shaft on opposite sides of the universal joint; rotating the collar and the shaft; seating the first self-energizing seal against the first shoulder; and seating a second self-energizing seal against the second shoulder. In one embodiment, the universal joint includes a convex surface formed on the shaft; a first concave surface extending circumferentially about the shaft and adapted to mate with the convex surface to carry a first axial load; and a spacer ring defining a second concave surface adapted to mate with the convex surface to carry a second axial load.

Systems and methods for conveying coiled tubing into a fluid conduit

SWIVEL CONNECTOR

Bore hole tool assembly, bearing system for use insuch a bore hole tool assembly, and method of des igning such a bore hole tool assembly.

Drill string tool

System for use in a bore hole for axially couplinga tubular end a mandrel, and a connecting assemblyfor such a system.

RINSING TUBE SEALS ARRANGEMENT

TELESKOPSTANGE FUER DEN TIEFBAU

LIFT-THROUGH HEAD AND SWIVEL

Downhole swivel apparatus and method

Downhole swivel apparatus and method

Bi-directional pressure energized axial seal and a swivel connection application

A tubular connection has first and second tubular members (11, 17) having aligned bores (19) with a common axis (21) and having first and second seal surfaces (29, 33), respectively. A metal seal (37) has a first end portion (41) that sealingly engages the first seal surface (29) and a second end portion (45) that sealingly engages the second seal surface (33). The metal seal (37) has a sidewall (47) with at least two folds (49, 51)). One of the folds (49) defines an axial interior gap. The other of the folds (51) defines an axial exterior gap. An exterior spacer member (61) is positioned in the exterior gap to limit closing of the exterior gap in response to a greater pressure on the interior of the seal (37) than on the exterior. An interior spacer member (55) is positioned in the interior gap to limit closure of the interior gap in response to a greater pressure on the exterior of the seal (37) than on the interior. &e LnI ...

Rotating and reciprocating swivel apparatus and method

What is provided is a method and apparatus wherein a rotating and reciprocating swivel of adjustable stroke length and shearable by ram blow out preventers can be detachably connected to an annular blowout preventer thereby separating the lower wellbore from the riser. In one embodiment the mandrel of the swivel being comprised of double box end joints and using double pin end subs to connect a plurality of such mandrel joints together.

UNIVERSAL JOINT ARRANGEMENT FOR DOWNHOLE TOOLS

The universal joint arrangement includes a first adapter having two projecting support formations; a drive plate having a first pair of matching depressions or pockets is seated with these depressions on the projecting support formations of the first adapter and the drive plate has a second pair of pockets for the projecting support formations of a respective second adapter.

LOCKING SWIVEL WITH REPLACEABLE INTERNAL GEAR MEMBERS

A locking swivel apparatus is provided. The locking swivel includes an upper body portion having a counter bore about a cylindrical axis and a mandrel receivable in the counter bore. The apparatus further includes a locking arrangement, including at least one replaceable gear member, disposed to engage with the upper body portion and the mandrel. The locking arrangement is further disposed to selectively couple and decouple the upper body portion and the mandrel, such selective coupling and decoupling disposed to correspondingly constrain and allow relative rotation of the upper body portion and the mandrel about the cylindrical axis. Embodiments of the locking swivel include two replaceable gears disposed to selectively engage and disengage one another.

FLEXIBLE COUPLING FOR DOWNHOLE DRIVE STRING

A flexible coupling for coupling sections of a downhole tubing string is provided. The flexible coupling has a central section with first and second ends, each end having a contact surface and a first part of a pivoting connector, the contact surface extending radially outward relative to the first part of the pivoting connector. The flexible coupling also has first and second coupling sections pivotally coupled to the first and second ends of the central section. Each of the first and second coupling sections have a tubing string attachment at a first end, a second part of the pivoting connector at a second end, and a contact surface at the second end, the contact surface extending radially outward relative to the second part of the pivoting connector. Pivotal movement of the first and second coupling sections relative to the central section is limited by engagement between the contact surfaces.

BEARING ASSEMBLY

A bearing assembly for use in an apparatus comprising a housing and a shaft, the shaft having a shaft axis and being rotatably connected with the housing, the housing defining an interior, an exterior and a first housing end. The shaft is comprised of a shaft extension extending from the interior of the housing at the first housing end, and the shaft extension defining a first bearing shaft surface. The bearing assembly comprises a first thrust bearing for transferring a first axial load between the shaft and the housing, the first thrust bearing located axially between the first housing end and the first bearing shaft surface. The first thrust bearing may be a rolling element bearing. The bearing assembly may further comprise a second thrust bearing for transferring a second axial load between the shaft and the housing, the second thrust bearing comprised of a preloading mechanism.

FLEXIBLE COLLAR FOR A ROTARY STEERABLE SYSTEM

A Rotary Steerable System (RSS) includes a flexible collar coupled therein that reduces the stiffness of the RSS and permits a tighter turning radius to be achieved. The positioning of the flexible collar between the steering section and the controller of the RSS further improves the turning radius, and may permit a push-the-bit system to operate similar to a point-the bit system. The flexible collar permits communication therethrough between controller and the steering sections of the RSS. The RSS may be arranged as a modular system to receive various configurations of a flexible collar and may operate with no flexible collar installed. The modularity enables tuning of the stiffness of an RSS to achieve different steering objectives.

TOP DRIVE SWIVEL APPARATUS AND METHOD

For use with a top drive power unit (10) supported for connection with a well string (20) in a well bore (14) to selectively impart longitudinal and/or rotational movement to the well string (20), a feeder (31) for supplying a pumpable substance such as cement and the like from an external supply source to the interior of the well string in the well bore without first discharging it through the top drive power unit (10) including a mandrel (40) extending through a sleeve (150) which is sealably and rotatably supported thereon for relative rotation between the sleeve (150) and mandrel (40). The mandrel (40) and sleeve (150) have flow passages (140, 190) for communicating the pumpable substance from an external source to discharge through the sleeve (150) and mandrel (40) and into the interior of the well string below the top drive power unit (10). The unit can include a packing injection system (225, 226) , clamp (600), and novel packing configuration (305).

WASHPIPE SEAL ASSEMBLY

A coupling seal assembly is described for directing a pressurized abrasive fluid between a non-rotating conduit member and a rotating second conduit member. The seal assembly includes a first ceramic floating seal member secured to the non- rotating conduit member and a second ceramic seal member secured to the rotating conduit member. Enhanced service life of the seal assembly under high pressures and high rotary speeds is achieved.

SYSTEM FOR USE IN A BORE HOLE FOR AXIALLY COUPLING A TUBULAR END AND A MANDREL, AND A CONNECTING ASSEMBLY FOR SUCH A SYSTEM

System for coupling two tubular ends for use in a well bore, the system comprising a first tubular end (4), a second tubular end (1) for inserting into the first tubular end in axial alignment thereof, thereby forming an annular space (31) between the first tubular end and the second tubular end, and a connecting assembly (16) for axially coupling the first tubular end with the second tubular end whereby the connecting assembly at least partly reaches in the annular space.

COILED TUBING SWIVEL ASSEMBLY

A coiled tubing swivel assembly is provided that includes a mandrel (102) for attachment to a pump (104), and a hub (106) rotatably attached to the mandrel and for attachment to an end of a string of coiled tubing (108). The mandrel and the hub together form a conduit for passage of a pumped substance. A crane bearing (112) is attached to the fluid conduit.

BI-DIRECTIONAL CV-JOINT FOR A ROTARY STEERABLE TOOL

An example downhole apparatus includes a drive shaft with a longitudinal axis, a spherical portion that extends radially from the longitudinal axis, and first and second interfacial surfaces proximate the spherical portion. An outer housing is positioned at least partially around the spherical portion. A radial bearing may be between the spherical portion and the outer housing and coupled to the outer housing. The radial bearing may comprise first and second interfacial surfaces in contact with the respective first and second interfacial surfaces of the drive shaft to transmit or receive torque in corresponding first and second rotational directions. A first axial bearing is coupled to the outer housing and in contact with a first end of the spherical portion to axially secure the drive shaft with respect to the outer housing.

METHODS AND SYSTEMS FOR ORIENTING A TOOL IN A WELLBORE

Methods and assemblies that can be used to orient a second pipe with respect to a first pipe in a wellbore are disclosed. The first pipe may be a casing string that includes one or more recessed latch couplings, and the second pipe may be a tubing string that includes one more complementary radially extendable latch keys that may be received within the latch couplings. The tubing string may include one or more switches associated with the latch keys that are actuated when the latch keys are received within the latch couplings. The actuation of the switches is communicated to an operator at the surface via control lines within the tubing string.

UNIVERSAL JOINT

A universal joint assembled in a drill string transfers torque between two components where rotation of the components may not be completely aligned. The universal joint includes upper and lower members with radial teeth connected by a serpentine retainer. As the joint rotates the members can pivot within the confines of the serpentine retainer to accommodate misalignment of the components. Axial force can be transferred through a bearing member between the members.

TENSION-SET TIEBACK PACKER

An apparatus for supporting tubing in casing includes a setting tool and a liner top packer, which can be used for tieback. A setting slip is disposed uphole of a packing assembly on the packer and is movable from a retracted to an extended state engaging the casing. The setting tool has a temporary connection to the packer and has a pack-off that seals the tool in the packer but allows for movement. After running downhole, the temporary connection of the setting tool to the packer is disconnected, and the setting slip is set in the casing by moving the setting tool in an uphole direction. To set the packing assembly, the packer is moved in the uphole direction by engaging the setting tool with the pack-off and compressing the packing element (e.g., packing element and opposing cones and slips) against the set setting slip. Eventually, the setting tool is disconnected from the packer by disengaging the pack-off.

CONSTANT-VELOCITY JOINT WITH SURFACE CONTACT FORKS

A constant-velocity joint can have three pieces: a yoke, a first adaptor, and a second adaptor. Grooves on opposite sides of the yoke can receive forks of the adaptors and be perpendicular to one another. The yoke can have a guide surface within each groove so that a matching following surface on the fork of the adaptor can engage the guide surface to guide the movement of the fork within the groove. The adaptors may pivot within the grooves such that surfaces of flanks of the forks remain engaged or provide a consistent amount of surface contact with flanks of the groove throughout the pivot of the forks. Torque can be transferred through the engaged flanks as the joint is used to convert eccentric rotation to concentric rotation.

A DOWNHOLE ASSEMBLY

A downhole assembly is disclosed and described for insertion into a borehole which addresses the problems associated with bit generated vibration, which are diminished. The assembly has a stabilizer sleeve element radially collocated about a bi-partite mandrel having an articulating and compliant metal-to-metal point of torque transfer and the stabilizer sleeve has a passive and active damping mechanisms associated therewith operating upon the bi-partite mandrel and located about the articulating and compliant metal-to-metal point of torque transfer.

HIGH LOAD UNIVERSAL JOINT FOR DOWNHOLE ROTARY STEERABLE DRILLING TOOL

A technique facilitates downhole drilling applications by providing a universal joint. The universal joint (24) has a high load carrying capability presented in a compact and simple configuration. The high load carrying capability is achieved by techniques employing unique load transfer mechanisms. For example, higher load capability may be provided by a load sharing principal in which torque loads are jointly transmitted through universal joint pins and the side faces of a universal joint cross (34). The higher load capability also may be achieved by transferring loads through a monolithic cross having integral pins and a split yoke/clevis assembly. In another embodiment, higher load capability results from using universal joint pins inserted from the inside of the universal joint and screwed outwardly until full engagement with the joint yokes is achieved. Each of the universal joint embodiments also may be designed to enable pressure-sealed flow of drilling mud through the joint.

FLEX JOINT FOR DOWNHOLE DRILLING APPLICATIONS

... ²A technique facilitates drilling applications by providing a unique flex ²joint. In one embodiment, the flex joint has ²an adjustable bending stiffness while being much more compact than ²conventional flex joints. The flex joint also may be designed ²to decouple bending moments from the tool joints and, in some applications, ²can operate as an active vibration and shock control ²sub by incorporating suitable sensors and a hydraulic actuator system. The ²design also enables incorporation of other features, ²such as electrical insulation features disposed above and/or below the flex ²joint. In some applications, the flex joint also may have ²an electrical feed through.² ...

A CONTINUOUS ROTARY DRILLING SYSTEM AND METHOD OF USE

A drilling system (20) has a drill string (26) that is made up of tubular segments (54) of coiled tubing joined together by connectors (56). The connectors can be selectively changed between locked and unlocked configurations. When in the unlocked configuration adjacent tubular segments rotate with respect to one another, and when in the locked configuration the tubular segments are rotationally affixed. The connectors include clutch members coupled to each tubular segment, that axially slide into a slot formed in an adjacent tubular segment to rotationally lock the adjacent segments. A Kelly bushing and rotary table (36) rotate the drill string; and an injector head (28) is used to insert the drill string through the Kelly bushing and rotary table and into a wellbore (40). While the drill string is inserted through the bushing and table, the connectors are set into the locked configuration so that all tubular segments from the rotary table downward are rotationally affixed.

APPARATUS FOR ANGULAR ALIGNMENT OF DOWNHOLE SENSORS WITH HIGH SIDE IN DIRECTIONAL DRILLING

Adjustment of the angle of a bent sub or other steering feature in a drill string relative to a reference angle of a downhole sensor is facilitated by a rotatable coupling between the bend sub and the sensor. The rotatable coupling may be rotated to align the high side with a reference indicia and locked at the set angle. Calibration of the sensor is facilitated and opportunities for certain measurement errors are eliminated. An embodiment provides a locking mechanism comprising tapered locking fingers which are clamped against a surface by a tapered collar. Rows of ceramic balls retained in circumferential channels may be provided to permit rotation while carrying tensile and compressional forces.

ROTARY LOCKING SUB FOR ANGULAR ALIGNMENT OF DOWNHOLE SENSORS WITH HIGH SIDE IN DIRECTIONAL DRILLING

Adjustment of the angle of a bent sub or other steering feature in a drill string relative to a reference angle of a downhole sensor is facilitated by a rotatable coupling between the bent sub and the sensor. The rotatable coupling may be rotated to align the high side with a reference indicium and locked at the set angle. Rows of ceramic balls retained in circumferential channels may be provided to permit rotation while carrying tensile and compressional forces. Calibration of the sensor is facilitated and opportunities for certain measurement errors are eliminated. An embodiment provides a mechanism for locking the rotatable coupling at a desired angle. The embodiment comprises a ring with teeth that engage a downhole portion of the coupling and depressions that engage an uphole portion of the coupling.

SYSTEM AND METHOD FOR OBSTACLE AVOIDANCE DURING HYDROCARBON OPERATIONS

A system and method for obstacle avoidance during hydrocarbon operations utilizing a non-vertical conduit between a vessel and associated subsea equipment. The system comprises a vessel and a conduit connected to the vessel with a first rotatable apparatus which is constructed and arranged to permit the vessel to rotate with respect to the conduit. The system also comprises a second rotatable apparatus connecting the conduit to subsea equipment secured to the seafloor. The second rotatable apparatus is constructed and arranged to permit the conduit to rotate with respect to the subsea equipment.

SPOOLABLE SWIVEL

A spoolable swivel, methods, and systems for coupling a first and second length of coiled tubing. The spoolable swivel can include an inner tubular element and an outer tubular element. The inner tubular element and the outer tubular element can both have dimpled distal ends and races on their proximal ends, defining one or more annular voids for swivel bearings.

DOWNHOLE CLUTCH WITH FLOW PORTS

A drill string tool (1) for use in a wellbore formed in an earth formation i s provided. The tool comprises a first element (1A) connectable to an upper drill string part (3) a second element (5) connectable to a lower drill string part (7) bearing means (11) allowing rotation of the first element relative to the second element about the longitudinal axis (9) of the drill string, and rotation transfer means (15) for transferring rotation of the first element about the longitudinal axis to the second element. Furthermore there is provided contr ol means (28) for selectively disengaging said rotation transfer means so as to selectively allow the first element to rotate relative to the second element by virtue of said bearing means. ...

DRILLING FIXTURE FOR THE FOUNDATION ENGINEERING.

LOCATED IN WELL CLUTCH WITH CHANNELS FOR FLOW

SYSTEM AND METHOD FOR DEVIATION FROM OBSTACLES DURING OPERATIONS IN PRODUCTION OF HYDROCARBONS

ШАРНИР-ВЕРТЛЮГ ДЛЯ БУРЕНИЯ СКВАЖИН

Шарнир-вертлюг (10) используется с оборудованием для бурения скважин с целью защиты спирально скрученного троса (62), который может представлять собой проволочный канат, трос и/или жгут, от воздействия крутящих усилий, а также обеспечивает угловое смещение груза-оттяжки или других инструментов во время операций извлечения каната для уменьшения взаимодействия с оборудованием буровой установки (80) при извлечении труб или инструментов (64) из устья скважины.

СИСТЕМА, ПРЕДНАЗНАЧЕННАЯ ДЛЯ ИСПОЛЬЗОВАНИЯ В СТВОЛЕ СКВАЖИНЫ ДЛЯ СОЕДИНЕНИЯ В ОСЕВОМ НАПРАВЛЕНИИ КОНЦА ТРУБЧАТОГО ЭЛЕМЕНТА И ОПРАВКИ, И СОЕДИНИТЕЛЬНЫЙ УЗЕЛ ДЛЯ ЭТОЙ СИСТЕМЫ

Система для соединения концов двух трубчатых элементов, предназначенная для использования в буровой скважине и содержащая конец (4) первого трубчатого элемента, конец (1) второго трубчатого элемента, предназначенный для вставки в конец первого трубчатого элемента соосно с ним и образования кольцевого пространства (31) между концом первого трубчатого элемента и концом второго трубчатого элемента, и соединительный узел (16), предназначенный для соединения в осевом направлении конца первого трубчатого элемента с концом второго трубчатого элемента, по меньшей мере, частично проходящий в кольцевом пространстве.

DOWNHOLE CLUTCH WITH FLOW PORTS

Axial high-pressure heavy-duty rotary joint

FACE SEAL WITH PRESSURIZED SEALING GASKETS

L'invention concerne un joint tournant pour transférer un premier fluide (Fi) comprenant un membre mâle (2) et un membre femelle (3) montés mobiles l'un par rapport à l'autre et concentriques, un ou plusieurs joints d'étanchéité annulaire (4a) hébergés au sein d'évidements aménagés dans ledit membre femelle (3) et éventuellement pressurisés au moyen d'un fluide d'isolation. L'invention concerne en outre un système de transfert de fluide comportant un ou plusieurs joints tournants (1, 1', 1'') selon l'invention.

TWO-WAY ROTARY SINGLE SWIVEL OF GROUND EXCAVATION DEVICE

The present invention relates to a two-way rotary single swivel of a ground excavation device and, more specifically, relates to a two-way rotary single swivel including a rotary supporter connected and assembled to an upper end of a drilling rod inserted and installed in a gear box body to be able to rotate and installed to rotate with the drilling rod and an upper fixating cap wherein a cement injection pipe inserted at the center of the rotary supporter to enable the rotary supporter to rotate and injecting cement supplied from outside into a cement supply pipe formed at the center of the drilling rod. The two-way rotary single swivel includes: a fixating outer container including upper and lower supporting bearings installed to press-fit inner rings into upper and lower parts of the rotary supporter and fixated and installed to cover the outer circumferences of outer rings of the upper and lower supporting bearings and the rotary supporter; a ring-shaped passage formed into a ring shape ...

LOAD SYSTEM

a solar energy collector for a downhole tool

SYSTEM FOR OBSTACLE AVOIDANCE DURING HYDROCARBON OPERATIONS

A system and method for obstacle avoidance during hydrocarbon operations utilizing a non-vertical conduit between a vessel and associated subsea equipment. The system comprises a vessel and a conduit connected to the vessel with a first rotatable apparatus which is constructed and arranged to permit the vessel to rotate with respect to the conduit. The system also comprises a second rotatable apparatus connecting the conduit to subsea equipment secured to the seafloor. The second rotatable apparatus is constructed and arranged to permit the conduit to rotate with respect to the subsea equipment.

Articulated coupling for use with a progressive cavity apparatus

A progressive cavity device including an articulate coupling for converting the complex motion of the rotor into simple rotation. The coupling includes two shafts coupled to one another by joint assemblies connected to opposite ends of an intermediate shaft. The joint assemblies include interlocked threaded portions and an elastomer filling the spaces between the threaded portions. Under loading the male and female portion move relative to one another so that the elastomer is subject to both compression and shear. Should the elastomer fail, the threaded portions simply lock together thereby allowing fail safe operation. The moving components within the coupling are perfectly isolated from the surrounding environment.

Articulated coupling

An articulated coupling has two cylindrical half-couplings facing each other at their end faces. Recesses are formed in the end faces which recesses in which a cage is installed in the recesses with a clearance. Radial coaxial openings are formed in the cage and the half-couplings and rollers are installed in the coaxial openings with clearances. The half-couplings are provided with a device for holding the rollers in the openings.

Dry pneumatic system for hard rock shaft drilling

A dry, vertical shaft drilling system including an inverted raiseboring cutterhead fitted with air nozzles and vacuum pickups. Weights are detachably stacked above the cutterhead. Cuttings are extracted through the weights into a swivel circumscribing the drill string. The swivel is a transition from the rotating cutterhead to the stationary extraction riser pipes disposed above the swivel. Non-rotating stabilizers stabilize the drill string.

Rotating and reciprocating swivel apparatus and method

What is provided is a method and apparatus wherein a swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve or housing can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve or housing of the swivel.

Method for downhole electrical transmission by forming an electrical connection with components capable of relative rotational movement

A method facilitates transmission of electric signals across well components which move relative to each other in a wellbore environment. The method utilizes well components which are movably, e.g. rotatably, coupled to each other via one or more conductive bearings. Each conductive bearing has a conductive rolling element which enables relative movement, e.g. rotation, between the well components while simultaneously facilitating transmission of electric signals through the bearing. The method also involves coupling portions of the bearing to each of the well components, and those bearing portions may be connected with electric leads to enable flow of electric signals through the bearing during operation of the system downhole.

Fracturing manifold systems and methods

A fracturing system is provided. In one embodiment, the fracturing system includes a fracturing manifold for routing fracturing fluid to multiple wells. The fracturing manifold can be coupled via fluid conduits to fracturing trees installed at the wells. In some cases, a fracturing tree is coupled to the fracturing manifold by a pair of goat heads in fluid communication with each other via at least one rigid fluid conduit. The fracturing manifold can include a trunk line that provides fracturing fluid to multiple outlet branches, which can include valves for controlling flow of fracturing fluid to wells downstream of the valves. Additional systems, devices, and methods are also disclosed.

ГИБКИЙ СОЕДИНИТЕЛЬ ДЛЯ БУРЕНИЯ С ПОГРУЖНЫМ ПНЕВМОУДАРНИКОМ

Группа изобретений относится к области бурения направленных скважин. Система обеспечения изгиба в стволе скважины содержит гибкий соединитель, имеющий первый компонент, образующий угол изгиба относительно второго компонента посредством универсального соединителя, и пружинный узел, регулируемый для изменения изгибной жесткости первого компонента относительно второго компонента. Гибкий соединитель дополнительно содержит датчик для измерения перемещения первого компонента относительно второго компонента. Система обеспечения изгиба дополнительно содержит систему привода, которая получает данные с датчика и реагирует для снижения вибрации. Обеспечивается повышение возможности отклонения скважины. 3 н. и 15 з.п. ф-лы, 3 ил.

СОЕДИНИТЕЛЬНЫЙ УЗЕЛ РАВНЫХ УГЛОВЫХ СКОРОСТЕЙ ДЛЯ БУРИЛЬНОЙ КОЛОННЫ

Группа изобретений относится к применяемому оборудованию и выполняемым работам, связанным со строительством подземной скважины, и предусматривает применение соединительного узла равных угловых скоростей для бурильной колонны. Технический результат - повышение надежности передачи вращения и крутящего момента между забойным двигателем и буровым долотом с помощью узла равных угловых скоростей. Соединительный узел равных угловых скоростей для бурильной колонны при передаче крутящего момента между забойным двигателем и буровым долотом содержит по меньшей мере один шаровой шарнир. При этом шаровой шарнир дополнительно содержит вторую ось, перпендикулярную первой оси, и вставку. Вставка имеет форму, обеспечивающую возможность ее вращения вокруг поперечной оси, перпендикулярной отверстию, проходящему поперечно сквозь шар шарнира. Гнездо шарового шарнира выполнено с возможностью вращения также и вокруг второй оси шарового шарнира с приспосабливанием к планетарному или эпициклическому движению ротора ...

СПОСОБ РЕКАВЕРИНГА РАБОЧЕГО СОСТОЯНИЯ НЕФТЕГАЗОДОБЫВАЮЩЕЙ СКВАЖИНЫ С ГОРИЗОНТАЛЬНЫМ И/ИЛИ СУБГОРИЗОНТАЛЬНЫМ ОКОНЧАНИЕМ В ПРОЦЕССЕ ЭКСПЛУАТАЦИИ И ТЕХНОЛОГИЧЕСКИЙ КОМПЛЕКС ДЛЯ ОСУЩЕСТВЛЕНИЯ СПОСОБА

Группа изобретений относится к нефтегазовой промышленности и предназначена для восстановления рабочего состояния скважины в процессе эксплуатации. Способ рекаверинга рабочего состояния нефтегазодобывающей скважины включает три этапа. На первом осуществляют геофизические измерения параметров скважины, по которым определяют профиль притока исследуемого участка скважины с выделением «неработающих интервалов». На втором этапе осуществляют промывку от техногенных жидкостей участков скважины с «неработающими» интервалами. На третьем этапе осуществляют контрольные измерения геофизических параметров скважины с определением качественных и количественных характеристик дебета «неработающих» интервалов. Технологический комплекс для реализации способа содержит две установки с колонной гибких насосно-компрессорных труб (ГНКТ), одна из которых содержит геофизический кабель для соединения и доставки в скважину геофизического прибора, а вторая установка ГНКТ служит для промывки призабойной части скважины ...

ЗАГРУЗОЧНАЯ СИСТЕМА

Изобретение относится к системам для передачи среды между двумя устройствами в удаленном от берега положении и способу соединения загрузочной системы. Загрузочная система для передачи, по меньшей мере, одной среды между первой установкой (4) и судном (3) содержит якорное устройство (5), которое закреплено относительно морского дна (1), по меньшей мере, один удлиненный первый передаточный элемент (6), который ориентирован вертикально, по меньшей мере, один гибкий второй передаточный элемент (7), расположенный в продолжении первого передаточного элемента (6), вертлюжное устройство (15), установленное между первым (6) и вторым (7) передаточными элементами и выполненное с возможностью вращения, по меньшей мере, вокруг продольной оси первого передаточного элемента (6). Свободный конец второго передаточного элемента (7), когда система не используется, расположен свободно свисающим в толще воды. Подъемное устройство для гибкого передаточного элемента (7) между первой установкой (4) и судном (3 ...

СКВАЖИННОЕ ВРАЩАЮЩЕЕСЯ УСТРОЙСТВО

Полезная модель относится к нефтедобывающей промышленности и может быть использована при эксплуатации нефтяных скважин, в частности в наклонных и горизонтальных скважинах, в качестве шарнирного соединения труб, скважинного инструмента или скважинного оборудования. Устройство состоит из внутреннего корпуса 1 с центральным отверстием для обеспечения прохода ловушек, уплотнений 2, 3, обеспечивающих герметичность внутренних плоскостей при вращении, на наружной поверхности внутреннего корпуса 1 установлена втулка 10 с внешним корпусом 8, между внешним и внутренним корпусами установлены шариковые радиальные 4, 5 и шариковые упорные подшипники 6, 7, поджатые гайкой 9. Все трущиеся поверхности скважинного вращающегося устройства находятся в герметичном объеме, заполненном маслом. Преимуществом заявляемого устройства является его высокая надежность работы за счет уменьшения износа уплотнительных элементов, повышение его несущей способности, что значительно увеличивает срок службы заявляемой буровой ...

Предварительно смонтированная заменяемая вставка бурового промывочного устройства

Изобретение относится к предварительно смонтированной заменяемой вставке бурового промывочного устройства для соединения стационарной промывочной трубы с вращающейся промывочной трубой буровой скважины. Вставка содержит механический уплотнительный узел со стационарным уплотнительным кольцом и вращающимся уплотнительным кольцом, первый носитель уплотнительного кольца, на котором расположено стационарное уплотнительное кольцо, второй носитель уплотнительного кольца, на котором расположено вращающееся уплотнительное кольцо, соединительный компонент, который выполнен с возможностью соединения заменяемой вставки со стационарной промывочной трубой, и регулирующий механизм, выполненный с возможностью действия в осевом направлении с винтовым соединением для изменения осевой длины заменяемой вставки, при этом винтовое соединение соединено со вторым носителем уплотнительного кольца для обеспечения регулирования в осевом направлении второго носителя уплотнительного кольца, механического уплотнительного ...

БУРОВОЕ ПРОМЫВОЧНОЕ УСТРОЙСТВО С ПРЕДВАРИТЕЛЬНО СМОНТИРОВАННОЙ ЗАМЕНЯЕМОЙ ВСТАВКОЙ

Изобретение относится к нефтегазодобывающей отрасли, в частности к промывочному оборудованию при бурении скважин. Устройство содержит стационарную промывочную трубу, вращающуюся промывочную трубу, предварительно смонтированную съемную заменяемую вставку для соединения стационарной промывочной трубы с вращающейся трубой. Заменяемая вставка содержит механический уплотнительный узел со стационарным уплотнительным кольцом и вращающимся уплотнительным кольцом, первый адаптер, который расположен между стационарной промывочной трубой и заменяемой вставкой. Первый адаптер содержит первый регулирующий механизм, выполненный с возможностью действия в осевом направлении для изменения осевой длины первого адаптера. Заменяемая вставка содержит второй регулирующий механизм, выполненный с возможностью действия в осевом направлении для изменения осевой длины заменяемой вставки. Упрощается конструкция, обеспечивается быстрая замена уплотнительного кольца. 14 з.п. ф-лы, 8 ил.

ШАРНИРНОЕ ЗВЕНО РАЙЗЕРА

Изобретение относится к шарнирному звену райзера. Шарнирное звено райзера содержит гибкое шаровое соединение с уплотнителями и расположенным внутри полости шара кардановым подвесом, который воспринимает осевые и радиальные нагрузки от струны райзера, когда шарнирное звено находится в разблокированном состоянии. Ось качания карданового подвеса располагается ниже верхнего кольцевого превентора. Гибкое шаровое соединение содержит запирающий механизм, оборудованный гладким патрубком и цилиндром с поршнем, запирающим элементом и пружиной. Механизм соединен с помощью гибкой трубки с обжимным патрубком, который содержит гидравлическую систему управления. Корпус цилиндра имеет один или несколько направляющих стержней, сопрягающихся с обжимным патрубком. Стержни препятствуют вращательному движению цилиндра относительно райзера. Технический результат изобретения заключается в снижении накопленных механических усталостных повреждений в устьевом оборудовании и в увеличении его срока эксплуатации и ...

ГИБРИДНАЯ РОТОРНАЯ УПРАВЛЯЕМАЯ СИСТЕМА И СПОСОБ

Роторная управляемая буровая система для бурения ствола скважины содержит утяжеленную бурильную трубу, буровое долото, вал долота, соединяющий буровое долото с утяжеленной бурильной трубой, причем вал долота соединен с утяжеленной бурильной трубой посредством соединения, выполненного с возможностью передавать крутящий момент от утяжеленной бурильной трубы на вал долота, и может поворачиваться относительно утяжеленной бурильной трубы вокруг соединения, первое эксцентриковое колесо и второе эксцентриковое колесо, соединенные с валом долота и вращающиеся для поворота вала долота относительно утяжеленной бурильной трубы вокруг соединения, контроллер для управления первым и вторым эксцентриковыми колесами для согласованного вращения, так что поворот вала долота относительно утяжеленной бурильной трубы, по существу, компенсирует вращение утяжеленной бурильной трубы, и активный стабилизатор, установленный на валу долота и выполненный с возможностью отклонения вала долота для создания бокового ...

СПОСОБ РЕКАВЕРИНГА РАБОЧЕГО СОСТОЯНИЯ НЕФТЕГАЗОДОБЫВАЮЩЕЙ СКВАЖИНЫ С ГОРИЗОНТАЛЬНЫМ И/ИЛИ СУБГОРИЗОНТАЛЬНЫМ ОКОНЧАНИЕМ В ПРОЦЕССЕ ЭКСПЛУАТАЦИИ И ТЕХНОЛОГИЧЕСКИЙ КОМПЛЕКС ДЛЯ ОСУЩЕСТВЛЕНИЯ СПОСОБА

... 1. Способ рекаверинга рабочего состояния нефтегазодобывающей скважины с горизонтальным и/или субгоризонтальным окончанием в процессе эксплуатации, включающий три этапа, на первом из которых осуществляют доставку геофизических приборов в скважину, с помощью которых производят измерение геофизических параметров скважины, включая измерение в пределах горизонтальной части ствола скважины, по которым определяют профиль притока исследуемого участка скважины с выделением «неработающих» интервалов, на втором этапе осуществляют промывку от техногенных жидкостей участков скважины, соответствующих выявленным «неработающим» интервалам профиля притока, на третьем этапе осуществляют контрольные измерения геофизических параметров скважины с определением качественных и количественных характеристик дебета участков, выделенных на первом этапе как «неработающих».2. Способ по п.1, характеризующийся тем, что при выявлении «неработающих» участков по итогам геофизических измерений в соответствии с третьим этапом ...

СКВАЖИННЫЙ ВЕРТЛЮЖНЫЙ ПЕРЕВОДНИК

Articulated universal joint with backlash reduction

Systems and methods for conveying coiled tubing into a fluid conduit

A system 10 for conveying coiled tubing 12 from a reel 14 into or from a hydrocarbons fluid conduit 16 comprises an injector in the form of injector head 18 suspended from a crane 20. The injector head 18 comprises a drive arrangement 28 typically comprising an arrangement of gripping members 30 to grip the coiled tubing 12 so the drive arrangement 28 can push and/or pull the coiled tubing 12 into or out of the fluid conduit 14. An access module 40 comprising a body 42 and a window 44 permits access to the coiled tubing 12. The system facilitates connection or disconnection of sections of the coiled tubing 12 avoiding tripping the coiled tubing connection through the injector 18 and around the tubing guide 24. Another system provides a tensioner (146, fig 2) to apply a tensile force to the coiled tubing. A coiled tubing (CT) connector can provide an unlocked state where two connected coiled tubes can pivot relative to one another, and a locked state where pivoting is prevented (figures ...

Downhole swivel sub

Downhole anchor

A downhole anchor 400, for use in a wellbore, comprising an elongate housing 402, at least two gripping members 410, movable relative to said housing 402, between a release position and a gripping position, in which each gripping member engages an internal surface of the wellbore, and a hydraulic gallery 404, within said housing, in fluid communication with a surface of at least two gripping members. The application of pressure to a hydraulic fluid, within the hydraulic gallery, causes said at least two gripping members, to move from the release position, to the gripping position. Said anchors may move radially only, the members 410 defining movable cylinders about pistons fixed to the housing 402. Three gripping members may be arranged as a set, about the longitudinal axis of the housing, at an angle of 120{ to one another (Fig. 4A), with each anchor comprising two of said sets, longitudinally spaced along the housing, and offset from each other by 60{. The gripping members may be retained ...

Downhole swivel joint

A ballistic tool for performing a downhole function

Downhole swivel joint assembly and method of using said swivel joint assembly

A downhole swivel joint assembly (18) comprised an upper component (18a) and a lower component (18b). The components may assume either of two stable positions relative to each other, namely an unactivated configuration (as shown in Figure 2) in which the components are rotationally fast with each other by virtue of the inter-engagement of splines (54) of the lower component with splines (56) of the upper component and an activated configuration in which the respective splines are disengaged so that the upper and lower components can rotate relative to each other. In the activated configuration the upper component is supported relative to the lower component on a ball bearing pack (42). Movement of the components between the activated and unactivated configurations is controlled by a resiliently deformable latch member (84) which is C-shaped in transverse cross-section. The latch member has an internal profile which cooperates with an external profile provided on the upper component mandrel ...

Swivel for use with expandable liners

A swivel 100 for use in a wellbore comprises a top body 90, a bottom body 80, and a sleeve 225. The sleeve can selectively causes the two bodies to rotate together in a first position (fig 1), or allow the bodies to rotate independently in a second position (fig 2). This is preferably achieved by engaging and disengaging co-operating sets of splines 240 associated with the sleeve and bodies. The sleeve may be actuated by a drop ball. The swivel device may be used in combination with a tubing expander tool.

Swivel/tilting bit crown for earth-boring drills

A drill bit 10 for drilling subterranean formations includes a device to provide a "universal" joint effect between the shank 14 and crown 12 for self alignment of the crown 12 with the bore hole in the formation. The bit is suitable for downhole assemblies configured for straight drilling, directional drilling and navigational drilling. The device can be incorporated into both drag bits and roller-type "rock". bits. Preferred embodiments include a flexible sub connecting the crown to the shank portion and having reduced stiffness relative to the drill string. Alternatively a spherical universal joint 20 or trunnion type universal is used. Replaceable lugs increase durability and reliability of the universal. The device equalizes the loads on cutters while reducing wear, average loads, and impact loads on cutters. Bore hole diameter, and chatter of the bit in the bore hole are reduced promoting maximum efficiency and rate of penetration as wobble and procession are minimized. ...

Swivel/tilting bit crown for earth-boring drills

Torque absorbtion anchor system and method to assemble same

An electric submersible pump (ESP) torque absorbtion anchor system (TAS) and a method to assemble the same are disclosed. The TAS includes a collar having an uphole end coupled to a production string and a flange formed on an outer diameter of the collar. The TAS also includes a sleeve having a rim extending radially inward from an uphole end of the sleeve. The collar is positioned in a cavity of the sleeve so that oppositely facing shoulders of the collar and the sleeve contact and transfer axial loads between the sleeve and the collar. A spring is positioned in an annulus between the sleeve and the collar and mounts to the collar and the sleeve so that rotational loading of the sleeve relative to the collar transfers to the spring.

Bearing Assembly

A bearing assembly for use in an apparatus having a housing and a shaft which is rotatably connected with the housing. A shaft extension extends from the interior of the housing at a first housing end. The shaft extension defines a first bearing shaft surface. The bearing assembly includes a first thrust bearing for transferring a first axial load between the shaft and the housing. The first thrust bearing is located axially between the first housing end and the first bearing shaft surface.

Rotating and reciprocating swivel apparatus and method

What is provided is a method and apparatus wherein a rotating and reciprocating swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections with the mandrel of the swivel being comprised of double box end joints and using double pin end subs to connect a plurality of such mandrel joints together.

Seal configuration for top drive swivel apparatus and method

For use with a top drive power unit supported for connection with a well string in a well bore to selectively impart longitudinal and/or rotational movement to the well string, a feeder for supplying a pumpable substance such as cement and the like from an external supply source to the interior of the well string in the well bore without first discharging it through the top drive power unit including a mandrel extending through a sleeve which is sealably and rotatably supported thereon for relative rotation between the sleeve and mandrel. The mandrel and sleeve have flow passages for communicating the pumpable substance from an external source to discharge through the sleeve and mandrel and into the interior of the well string below the top drive power unit. The unit can include a packing injection system and novel seal configuration.

ROTATING AND RECIPROCATING SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus wherein a rotating and reciprocating swivel of adjustable stroke length and shearable by ram blow out preventers can be detachably connected to an annular blowout preventer thereby separating the lower wellbore from the riser. In one embodiment the mandrel of the swivel being comprised of double box end joints and using double pin end subs to connect a plurality of such mandrel joints together. 1. A method of creating a rotating and reciprocating swivel tool while located on a drilling rig or platform having a specified stroke length , comprising the steps of:(a) providing a swivel tool, the swivel tool comprising a mandrel and a sleeve/housing, the mandrel being rotatable and reciprocable relative to the sleeve/housing, the mandrel having a first stroke length relative to the sleeve/housing;(b) supporting in a substantially vertical direction the swivel tool at the rig;(c) adding a mandrel joint to the top of the mandrel, such additional joint increasing the stroking length of the mandrel relative to the first stoking length;(d) lowering the swivel tool and again supporting in a vertical direction the swivel tool in a substantially vertical direction on the rig; and(e) repeating steps “c” and “d” until the final stroking length of the mandrel relative to the sleeve/housing is at least 100 feet.2. The method of claim 1 , wherein steps “c” and “d” can be repeated until the final stroking length can be greater than about 150 feet.36-. (canceled)7. The method of claim 1 , wherein in step “e” a plurality of the mandrel joints include at least one recessed area in the exterior sealing surface claim 1 , and during step “c” one of these recessed areas are used to support the swivel tool in a substantially vertical direction on the rig.8. The method of claim 7 , wherein at least one of the recessed areas includes soft material transition sections.9. The method of claim 7 , wherein the upper portions of the recessed areas are be ...

Quick Connect Coupling for Cementing Operations and the Like

Devices and methods for quickly connecting and disconnecting a conduit to a port. In a described embodiment, a quick connect coupling is described for quickly connecting and disconnecting a cement supply conduit to the port of a top drive cement swivel. 1. A coupling for releasably connecting a fluid conduit to a port , the coupling comprising:a stinger assembly affixed to the conduit, the stinger assembly having a generally cylindrical stinger for carrying fluid from the fluid conduit to the port and a generally cylindrical breech lock barrel radially surrounding the stinger and presenting at least one raised key thereupon;a breech lock connector associated with the port, the breech lock connector comprising a bore that is shaped and sized to receive the stinger and the breech lock barrel therein and having at least one radially inwardly projecting ridge and;wherein, the stinger assembly can be secured to the breech lock connector by inserting the stinger assembly within the bore at a rotational angle wherein the at least one key is angularly unaligned with the at least one ridge and then rotating the stinger assembly so that the at least one key is located behind and angularly in line with the at least one ridge.2. The coupling of further comprising a locking arrangement for securing the stinger assembly against rotation within the breech lock connector.3. The coupling of wherein the locking arrangement comprises:a locking pin associated with the port that is moveable between a first, unlocked position and a second, locked position; andan indentation associated with the stinger assembly into which the locking pin is seated when in the locked position.4. The coupling of further comprising a handle that radially surrounds the stinger.5. The coupling of wherein there is a plurality of keys and a plurality of ridges.6. The coupling of further comprising a lifting eye for lifting the stinger assembly.7. The coupling of further comprising:an anti-rotation dog located on ...

DOUBLE SWIVEL APPARATUS AND METHOD

A double swivel for use with a top drive power unit supported for connection with a well string in a well bore to selectively impart longitudinal and/or rotational movement to the well string, a feeder for supplying a pumpable substance such as cement and the like from an external supply source to the interior of the well string in the well bore without first discharging it through the top drive power unit including a mandrel extending through double sleeves which are sealably and rotatably supported thereon for relative rotation between the sleeves and mandrel. The mandrel and sleeves have flow passages for communicating the pumpable substance from an external source to discharge through the sleeve and mandrel and into the interior of the well string below the top drive power unit. The unit can include a packing injection system, clamp, and novel packing configuration. In an alternative embodiment the unit can include a plug or ball insertion tool. 1. A double top drive swivel insertable into a drill or work string comprising:(a) a first mandrel having upper and lower end sections, the upper section being connectable to and rotatable with an upper drill or work string section, the first mandrel including a longitudinal passage;(b) a first sleeve, the first sleeve being rotatably connected to the first;(c) a first seal between upper and lower end portions of the first mandrel and first sleeve, the first seal preventing leakage of fluid between the first mandrel and first sleeve;(d) the first sleeve comprising an inlet port;(e) the first mandrel comprising a plurality of longitudinally spaced apart radial ports in fluid communication with both the inlet port of the first sleeve and the longitudinal passage of the first mandrel to supply pressurized fluid from the inlet port of the first sleeve to the longitudinal passage of the first mandrel;(f) a second mandrel having upper and lower end sections, the upper section being fluidly connected to the lower section of the ...

ROTATING AND RECIPROCATING SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus wherein a swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve or housing can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve or housing of the swivel. 1. A marine oil and gas well drilling apparatus comprising:(a) a marine drilling platform;(b) a drill string that extends between the marine drilling platform and a formation to be drilled, the drill string having a flow bore;(c) a mandrel having upper and lower end sections and connected to and rotatable with upper and lower sections of the drill string, the mandrel having an external diameter and including a longitudinal passage forming a continuation of a flow bore of the drill string sections;(d) a sleeve having a longitudinal sleeve passage and an internal diameter, the sleeve being rotatably connected to the mandrel;(e) an interstitial space between the internal diameter of the sleeve and the external diameter of the mandrel;(f) a pressure relief mechanism that gradually relieves the interstitial space when the mandrel and sleeve are elevated in a well bore.2. The marine oil and gas well drilling apparatus of claim 1 , wherein the pressure relief mechanism includes a pair of spaced apart packing units.3. The marine oil and gas well drilling apparatus of claim 1 , wherein the packing units are placed in opposing sealing directions.4. The marine oil and gas well drilling ...

LOAD-BEARING UNIVERSAL JOINT WITH SELF-ENERGIZING SEALS FOR A ROTARY STEERABLE DRILLING TOOL

A rotary steerable drilling tool and a method according to which a universal joint is sealed. In one embodiment, the method includes providing the collar, the shaft, the universal joint, and first and second shoulders between which the universal joint is positioned; providing first and second self-energizing seals between the collar and the shaft on opposite sides of the universal joint; rotating the collar and the shaft; seating the first self-energizing seal against the first shoulder; and seating a second self-energizing seal against the second shoulder. In one embodiment, the universal joint includes a convex surface formed on the shaft; a first concave surface extending circumferentially about the shaft and adapted to mate with the convex surface to carry a first axial load; and a spacer ring defining a second concave surface adapted to mate with the convex surface to carry a second axial load. 1. A rotary steerable drilling tool adapted to be disposed within a wellbore , the rotary steerable drilling tool comprising:a collar defining an interior surface and a first longitudinal axis;a shaft extending within the collar, the shaft defining an exterior surface and a second longitudinal axis;a universal joint adapted to transfer rotation from the collar to the shaft when the collar is rotated;a convex surface connected to the shaft and extending circumferentially thereabout;a first concave surface extending circumferentially about the shaft, the first concave surface adapted to mate with the convex surface to carry a first axial load applied to the shaft in a first direction;wherein the first axial load is applied to the shaft when the first and second longitudinal axes are spaced in either an oblique relation or a parallel relation.2. The rotary steerable drilling tool of claim 1 , wherein the rotary steerable drilling tool further comprises a spacer ring disposed within the collar claim 1 , the spacer ring comprising:a second concave surface extending ...

Segmented Bend-Limiter for Slickline Rope Sockets and Cable-Heads

A chain of bend-limiter segments is coupled together. The chain has a first end and a second end. The chain is bendable such that an angle between the first end and the second end is at least N degrees and a radius of curvature of the chain is at least M. A cable is inserted through the chain from the first end to the second end. The chain and the cable are coupled to a tool. The tool is pulled using the cable. The chain maintains a radius of curvature of the cable greater than M and prevents a stress level in the cable from exceeding a yield point. 1. A method comprising:coupling together a chain of bend-limiter segments, the chain having a first end and a second end, the chain being bendable such that an angle between the first end and the second end is at least N degrees and a radius of curvature of the chain is at least M;inserting a cable through the chain from the first end to the second end;coupling the chain and the cable to a tool;pulling the tool using the cable, the chain maintaining a radius of curvature of the cable greater than M and preventing a stress level in the cable from exceeding a yield point.2. The method of further comprising:coupling the cable to a surface equipment;deploying the chain of bend-limiter segments, the tool, and the cable into a borehole, past a first location where the borehole deviates;wherein pulling the tool using the cable comprises retrieving the tool from the deviated borehole when the tool passes through the first location.3. The method of wherein pulling the tool using the cable comprises lifting the tool from a first orientation to a second orientation different from the first orientation using the cable.4. The method of wherein coupling together a chain of bend-limiter segments comprises coupling two or more bend-limiter segments.5. The method of wherein coupling together a chain of bend-limiter segments comprises:dividing the bend-limiter segments into two or more halves;mounting the two or more halves about the ...

SWIVEL JOINT FOR OILFIELD PUMPING STIMULATION

A swivel joint includes a tubular female member which is rotatably connected to a tubular male member. The female member includes a female race portion having an axially extending inner annular recess, a female inner end portion which is formed at an axially inner end of the recess, and a number of inner annular grooves which are formed in the recess coaxially therewith. The male member includes a male race portion having an annular outer surface which is configured to be received in the recess, a male nose portion which is formed at an end of the male race portion, and a number of outer annular grooves which are formed on the outer surface coaxially therewith. The male race portion is positioned in the female race portion such that the male nose portion is located adjacent the female inner end portion and each outer groove is aligned with a corresponding inner groove to thereby define a number of annular bearing races within which a plurality of balls are received to thereby rotatably connect the male member to the female member. A first primary seal is positioned between the male nose portion and the female inner end portion, and a second seal is positioned between the male nose portion and the female inner end portion radially outwardly of the first primary seal. The male nose portion comprises an end wall which extends radially outwardly from the flow bore and a conical side wall which extends both radially and axially outwardly relative to the cylindrical side wall, and the second seal comprises at least a first portion which sealingly engages the conical side wall. 1. A swivel joint comprising:a tubular female member which includes a female race portion having an axially extending inner annular recess, a female inner end portion which is formed at an axially inner end of the recess, and a number of inner annular grooves which are formed in the recess coaxially therewith;a tubular male member which includes a male race portion having an annular outer surface ...

DOWNHOLE SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus which can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve of the swivel. 118-. (canceled)19. A swivel insertable into a drill or work string comprising:(a) a mandrel having upper and lower end sections rotatable with upper and lower drill or work string sections, the mandrel including a longitudinal passage forming a continuation of a passage in the drill or work string sections;(b) a sleeve being rotatably and reciprocably with respect to the mandrel;(c) a plurality of packing units between upper and lower end portions of the mandrel and the sleeve, the plurality of packing units preventing leakage of fluid between the mandrel and the sleeve, at least one of the packing units in the plurality of packing units comprising a rope seal.201. The swivel of claim , wherein the sleeve is reciprocable between the upper and lower end sections of the mandrel.221. The swivel of claim , wherein the non-rope seal comprises metal filled teflon.231. The swivel of claim , wherein the non-rope seal comprises bronze filled teflon.24. A method of performing operations in a wellbore , the method comprising the following steps:(a) attaching a swivel to a drill string, the swivel including a mandrel having a longitudinal axis and a sleeve, the sleeve being rotatably connected to the mandrel with the sleeve ...

Whipstocking drill for ultra-short-radius well

The invention belongs to the technical field of drills for petroleum, coal mines and exploration, and provides a whipstocking drill for an ultra-short-radius well. The whipstocking drill comprises several flexible drill rods which are sequentially connected end to end, wherein the flexible drill rod at an end portion is connected with a length compensation device, and the flexible drill rods are externally sleeved with several guide sleeves which are movably connected. The invention solves the technical problems of a long whipstocking length and an excessively large turning radius of curvature during whipstocking.

Downhole swivel apparatus and method

What is provided is a method and apparatus which can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve of the swivel.

ENERGY HARVESTING SYSTEM

A system, in certain embodiments, includes a joint and an energy harvesting system. The energy harvesting system includes an energy conversion system configured to convert kinetic energy from movement of the joint into electrical energy. 120.-. (canceled)21. An energy harvesting system , comprising: a first component comprising cantilevered element having a piezoelectric element; and', 'a second component comprising a surface, wherein the surface comprises a plurality of rigid members, the first component and the second component are coupled to one another, and the cantilevered element is configured to engage with the plurality of rigid members of the surface as the first component and the second component move relative to one another., 'a mineral extraction system joint, comprising22. The system of claim 21 , wherein the piezoelectric sensor is configured to convert kinetic energy created when the cantilevered element engages with the plurality of rigid members into electrical energy.23. The system of claim 21 , wherein the plurality of rigid members comprises a plurality of teeth extending outwardly from the surface.24. The system of claim 23 , wherein each tooth of the plurality of teeth is spaced generally equidistantly from one another.25. The system of claim 23 , wherein the cantilevered element comprises an arm portion configured to contact the plurality of teeth as the first component and the second component move relative to one another.26. The system of claim 25 , wherein the arm portion of the cantilevered element comprises plastic claim 25 , metal claim 25 , a composite material claim 25 , or a combination thereof27. The system of claim 21 , wherein plurality of rigid members comprises a plurality of recesses formed in the surface.28. The system of claim 27 , wherein each recess of the plurality of recesses is spaced generally equidistantly from one another.29. The system of claim 27 , wherein the cantilevered element comprises a ball coupled to a spring ...

ADJUSTABLE FRACTURING SYSTEM

An adjustable fracturing system is provided. In one embodiment, the system includes a fracturing manifold and a fracturing tree. A fluid conduit is coupled between the fracturing manifold and the fracturing tree to enable receipt of fracturing fluid by the fracturing tree from the fracturing manifold. Further, the fluid conduit is an adjustable fluid conduit that allows an operator to vary a dimension of the fluid conduit to facilitate coupling of the fluid conduit between the fracturing manifold and the fracturing tree. Additional systems, devices, and methods are also disclosed. 1. A system comprising:a fracturing manifold;a fracturing tree; anda fluid conduit coupled between the fracturing manifold and the fracturing tree to enable receipt of fracturing fluid by the fracturing tree from the fracturing manifold, wherein the fluid conduit is an adjustable fluid conduit that allows an operator to vary a dimension of the fluid conduit to facilitate coupling of the fluid conduit between the fracturing manifold and the fracturing tree, the fluid conduit includes a plurality of pipe joints coupled to one another, and the plurality of pipe joints includes multiple swivel connections that enable multiple rotational degrees of freedom in aligning the fluid conduit between the fracturing manifold and the fracturing tree.2. (canceled)3. The system of claim 1 , wherein the plurality of pipe joints are coupled to one another with connection blocks.4. The system of claim 1 , wherein the plurality of pipe joints are coupled to one another with elbow blocks.5. The system of claim 4 , wherein at least one of the pipe joints is coupled between a first elbow block and a second elbow block claim 4 , the at least one pipe joint coupled to the first elbow block with a swivel connection claim 4 , of the multiple swivel connections claim 4 , that enables the at least one pipe joint and the second elbow block to rotate with respect to the first elbow block about the axis of the at least ...

MULTIFUNCTION WELLBORE TUBULAR PENETRATION TOOL

A wellbore intervention tool includes a housing and a means for locking the housing at a selected position inside a first wellbore pipe. The tool includes means for penetrating the first wellbore pipe extensible from the housing. The means for penetrating includes means for measuring an amount of extension thereof or an amount of force exerted thereby such that the means for penetrating is controllable to penetrate the first wellbore pipe without penetration of a second wellbore pipe in which the first wellbore pipe is nested. 1. A wellbore intervention tool , comprising:a housing;means for locking the housing at a selected position inside a first wellbore pipe;means for penetrating the first wellbore pipe extensible from the housing, the means for penetrating comprising means for measuring an amount of extension thereof or means for measuring an amount of force exerted thereby such that the means for penetrating is controllable to penetrate the first wellbore pipe without penetration of a second wellbore pipe in which the first wellbore pipe is nested.2. The wellbore intervention tool of wherein the means for locking comprises at least one laterally extensible arm.3. The wellbore intervention tool of wherein the means for locking comprises at least one radially expandable annular flexible element.4. The wellbore intervention tool of wherein at least one radially expandable annular flexible element comprises an inflatable packer.5. The wellbore intervention tool of further comprising ports in the housing disposed longitudinally outside a longitudinal zone defined by the two inflatable packers claim 4 , the ports coupled to valves operable to selectively establish fluid communication between longitudinal zones defined by the at least two inflatable packers.6. The wellbore intervention tool of further comprising at least one pump and selectively operable valves in fluid communication with a space inside the longitudinal zone and outside the longitudinal zone whereby ...

DEVICE FOR TERMINATION OF A RISER IN A FLOATING STRUCTURE

A device for coupling a riser comprises a flexible joint comprising flanges, a ball joint with a housing comprising a mating face; a connection pipe comprising flanges; a guide pipe comprising a hang off face; a hang off structure underneath a flange of the connection pipe comprising a coned section with a surface contacting the connection pipe, a spline having parts fitting into the connection pipe, hang off segments attached to the hang off structure, the segments providing a load transferring surface; and an adapter fastened to the flexible joint housing comprising a mating surface complementary to a mating surface of the flexible joint housing; support regions; a coned section above a support region, ending at a distance from the hang off structure and in contact with the connection pipe; at least one of the support regions and the flexible joint housing being in contact with the guide pipe. 2. The device according to wherein the adapter is split in two or more sections in a longitudinal direction which are bolted together and supplied with grooves and tongues at interfaces of the two or more sections in order to prevent the two or more sections from sliding when bending forces are applied.3. The device according to claim 1 , wherein the two or more sections of the adapter are held together at a top end by a securing ring comprising one or more parts bridging the two or more sections of the adapter and being bolted to the top end by bolts entering the adapter in a direction parallel with an axis of the adapter.4. The device according to wherein the adapter is in one piece having an inner diameter which is slightly larger than an inner diameter of the upper flange of the connection pipe.5. The device according to claim 1 , wherein the connection pipe is provided with protrusions in the circumferential support region(s) along the length of the connection pipe filling a gap between the connection pipe and the adapter.6. The device according to wherein the guide ...

ROTATING AND RECIPROCATING SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus wherein a swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve or housing can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve or housing of the swivel. 130-. (canceled)31. A method of using a reciprocating swivel in a drill or work string , the method comprising the following steps:(a) lowering a rotating and reciprocating tool to an annular BOP, the tool comprising a mandrel and a sleeve, the sleeve being reciprocable relative to the mandrel and the swivel including a quick lock/quick unlock system which has locked and unlocked states, the swivel including an interstitial space between the sleeve and the mandrel, the interstitial space having an interstitial pressure relief mode and an interstitial non-pressure relief mode, the swivel being reversably switchable between pressure relief and non-pressure relief modes;(b) after step “a”, having the annular BOP close on the sleeve;(c) causing relative longitudinal movement between the sleeve and the mandrel and activating the quick lock/quick unlock system to cause the quick lock/quick unlock to change from an unlocked to a locked state.32. The method of claim 31 , wherein in step “a” claim 31 , the sleeve is longitudinally locked relative to the mandrel.33. The method of claim 31 , wherein claim 31 , after step “b” and before step “c” claim 31 , the sleeve is unlocked longitudinally ...

ROTATING AND RECIPROCATING SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus wherein a rotating and reciprocating swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections with the mandrel of the swivel being comprised of double box end joints and using double pin end subs to connect a plurality of such mandrel joints together. 1. A method of using a reciprocating swivel in a drill or work string , the method comprising the following steps:(a) lowering a rotating and reciprocating tool to a blow out preventer, the tool comprising a mandrel and a sleeve, the sleeve being reciprocable relative to the mandrel and the mandrel including at least one joint having double box ends with the joint being severable by a ram blow out preventer, the sleeve having two spaced apart sealing units, the swivel including an interstitial space between the sleeve and the mandrel with first and second spaced apart sealing units each sealing the interstitial space;(b) after step “a”, having the annular blow out preventer close on the sleeve; and(c) after step “b”, causing relative longitudinal movement between the sleeve and the mandrel, wherein in step “a” the mandrel includes two double box end joints which are connected by a double pin end sub, and in step “c” when the double pin end sub is at the same longitudinal position as the first sealing unit, the first sealing unit loses its seal of the interstitial space, but the second sealing keeps its seal of the interstitial space.2. The method of claim 1 , wherein after the double pin end sub passes by the first sealing unit claim 1 , the first sealing unit regains its seal of the interstitial space.3. The method of claim 2 , wherein when the double pin end sub is at the same longitudinal position as the second sealing unit claim 2 , the second sealing unit loses its seal of the interstitial space claim 2 , but the first sealing keeps its seal of the interstitial space.4. The method of ...

U-Joint With High Torque Capacity And Improved Thrust Bearing Capacity

An assembly, apparatus, and method relate to a downhole motor drive shaft assembly drilling a subterranean wellbore. The assembly includes a drive shaft having a longitudinal rotational axis, a plurality of drive key sockets, an end housing having a longitudinal rotational axis, a plurality of circumferentially spaced axial keyways, and a concave spherical thrust bearing surface, and a drive key operatively connecting each drive key socket with a respective axial keyway for transferring torque from the drive shaft to the end housing. The drive key includes a substantially planar drive face slidably engaging the axial keyway, and a radiused, cylindrical back portion rotatably engaging the drive key socket, the substantially planar drive face and radiused, cylindrical back portion forming a nominal half-circle. 1. A downhole motor drive shaft assembly comprising:a drive shaft having a first end, a second end, a longitudinal rotational axis, and a thrust insert socket located proximate one of the first end and the second end;an end housing having a longitudinal rotational axis and a concave spherical thrust bearing surface;a thrust bearing insert disposed within the thrust insert socket and a convex spherical surface in mating engagement with the concave spherical thrust bearing surface of the end housing; anda mechanism for transferring torque from the drive shaft to the end housing, the mechanism for transferring torque configured to be operationally effective irrespective of any relative angular offset between the rotational axes of the drive shaft and the end housing over a selected angular range;the torque transferring mechanism comprising a plurality of drive keys with a planar front face and a cylindrical back face, the two faces forming a nominal half-circle;wherein the thrust bearing insert comprises a material selected from the group consisting of a copper-nickel-tin alloy, an iron-chromium-nickel-manganese-silicon alloy, a copper-beryllium alloy, a cobalt- ...

FRACTURING MANIFOLD SYSTEMS AND METHODS

A fracturing system is provided. In one embodiment, the fracturing system includes a fracturing manifold for routing fracturing fluid to multiple wells. The fracturing manifold can be coupled via fluid conduits to fracturing trees installed at the wells. In some cases, a fracturing tree is coupled to the fracturing manifold by a pair of goat heads in fluid communication with each other via at least one rigid fluid conduit. The fracturing manifold can include a trunk line that provides fracturing fluid to multiple outlet branches, which can include valves for controlling flow of fracturing fluid to wells downstream of the valves. Additional systems, devices, and methods are also disclosed. 1. A system comprising:a fracturing manifold;a plurality of fracturing trees;a plurality of fluid conduits coupled between the fracturing manifold and the plurality of fracturing trees to enable receipt of fracturing fluid by the plurality of fracturing trees from the fracturing manifold;a first goat head; anda second goat head;wherein a fracturing tree of the plurality of fracturing trees is coupled to the fracturing manifold via the first goat head, the second goat head, and at least one rigid fluid conduit of the plurality of fluid conduits, and wherein the first goat head and the second goat head are in fluid communication with each other via the at least one rigid fluid conduit.2. The system of claim 1 , wherein the fracturing manifold includes:a shared trunk conduit for routing fracturing fluid to multiple fracturing trees of the plurality of fracturing trees; andoutlet branches for routing fracturing fluid from the shared trunk conduit to individual fracturing trees of the multiple fracturing trees.3. The system of claim 2 , wherein the outlet branches of the fracturing manifold include valves to individually control flow of fracturing fluid from the shared trunk conduit to the multiple fracturing trees.4. The system of claim 3 , wherein the outlet branches of the fracturing ...

METHODS AND SYSTEMS FOR REDUCING DRAG AND FRICTION DURING DRILLING

A rotating flow coupler that is configured to couple multiple sections of a casing for a horizontal well, wherein the rotating flow coupler is configured to rotate relative to the casing allowing an additional degree of freedom for equipment being lowered into the well. This may allow for equipment such as coil tubing, drilling string, casings strings, etc. to reach a total distance of deeper laterals. 1. A rotating flow coupler comprising:an outer tool positioned between a first casing element and a second casing elementan inner tool configured to be positioned adjacent to an inner diameter of the outer tool, the inner tool configured to rotate relative to the outer tool, wherein the inner tool is positioned between the first casing element and the second casing element.2. The rotating flow coupler of claim 1 , wherein an outer circumference of the outer tool is positioned proximate to sidewalls of a borehole.3. The rotating flow coupler of claim 1 , further comprising:a seal positioned between the inner tool and the outer tool, the seal being configured to restrict fluid from flowing in-between the inner tool and the outer tool.4. The rotating flow coupler of claim 1 , further comprising:a bearing configured to allow the inner tool to rotate independently from rotation of the outer tool.5. The rotating flow coupler of claim 1 , wherein the outer tool is longitudinally aligned with the inner tool within a wellbore.6. The rotating flow coupler of claim 1 , wherein the first casing element includes an inner casing and an outer casing.7. The rotating flow coupler of claim 6 , further comprising:a first crossover being configured to couple the outer casing and the outer tool.8. The rotating flow coupler of claim 6 , wherein the outer casing is directly coupled to the outer tool.9. The rotating flow coupler of claim 8 , wherein the inner casing is directly coupled with the inner tool.10. The rotating flow coupler of claim 6 , wherein a first diameter across the inner ...

DOWNHOLE SWIVEL SUB AND METHOD FOR RELEASING A STUCK OBJECT IN A WELLBORE

In certain embodiments, a downhole swivel sub includes a first swivel part configured to connect to a first section of a workstring, and a second swivel part configured to connect to a second section of the workstring. The second swivel part is rotatable relative to the first swivel part. The downhole swivel sub also includes a locking sleeve rotationally coupled with the first swivel part and movable axially between a locking position wherein the first swivel part and the second swivel part are rotationally coupled and an unlocking position wherein the first swivel part is rotatable relative to the second swivel part. The locking sleeve includes at least two first rows of teeth disposed at a same radial position and separated axially on the locking sleeve. The at least two first rows of teeth are configured to engage and disengage with at least two second rows of teeth located on the second swivel part. 115.-. (canceled)16. A downhole swivel sub comprising:a first swivel part configured to connect to a first section of a workstring;a second swivel part configured to connect to a second section of the workstring, wherein the second swivel part is rotatable relative to the first swivel part; anda locking sleeve rotationally coupled with the first swivel part and movable axially between a locking position wherein the first swivel part and the second swivel part are rotationally coupled and an unlocking position wherein the first swivel part is rotatable relative to the second swivel part, wherein the locking sleeve comprises at least two first rows of teeth disposed at a same radial position and separated axially on the locking sleeve, wherein the at least two first rows of teeth are configured to engage with at least two second rows of teeth located on the second swivel part when the locking sleeve is in the locking position, and the first rows of teeth are configured to disengage from the second rows of teeth of the second swivel part when the locking sleeve is in ...

MUD MOTOR TRANSMISSION

A double knuckle coupling suitable for transmitting torque applied to a first input shaft to a second shaft wherein the coupling accommodates angular changes between the shafts. Additionally, the disclosure describes an improved mud motor transmission incorporating the coupling. 1. A drive shaft comprising:a first input shaft having a first end and a second end, said second end having at least one recessed slot and at least one outwardly projecting ridge;a second input shaft having a first end and a second end, said first end having at least one recessed slot and at least one outwardly projecting ridge;a wear disk having a first wear surface and a second wear surface, said first wear surface having at least one outwardly projecting ridge and at least one recessed slot, said second wear surface having at least one outwardly projecting ridge and at least one recessed slot;said wear disk positioned between said second end of said first input shaft and said first end of said second input shaft such that ridges carried by said input shafts are received within said slots of said wear disk;a double knuckle coupling carried by the second end of the second input shaft; said double knuckle coupling comprising an input shaft, a center shaft and a center coupling element.2. A double knuckle coupling comprising:an input shaft, a centering element and an output shaft.3. A double knuckle coupling comprising:an input shaft, said input shaft having a first end and a second end, said second end has a slot defining a tongue and groove configuration wherein each tongue has an arcuate recess;an output shaft, said output shaft having a first end and a second end, said first end has a slot defining a tongue and groove configuration wherein each tongue has an arcuate recess;a center coupling element, said center coupling element has a first tongue configured to be received within said slot of said second end of said input shaft and a second tongue configured to be received within the slot ...

SYSTEMS AND METHODS FOR LOCKING SWIVEL JOINTS WHEN PERFORMING SUBTERRANEAN OPERATIONS

A system for performing subterranean operations is disclosed. The system includes a coiled tubing having a first segment and a second segment. The system further includes a swivel joint positioned at an interface of the first segment and the second segment and a locking mechanism. The locking mechanism is operable to engage and disengage the swivel joint. 1. A system for performing subterranean operations comprising: 'wherein the coiled tubing comprises a first segment and a second segment;', 'a coiled tubing;'} 'wherein the swivel joint is positioned at an interface of the first segment and the second segment; and', 'a swivel joint;'} 'wherein the locking mechanism is operable to engage and disengage the swivel joint.', 'a locking mechanism;'}2. The system of claim 1 , wherein when the swivel joint is engaged claim 1 , the first segment is rotationally coupled to the second segment.3. The system of claim 1 , wherein the swivel joint comprises a first portion and a sleeve portion.4. The system of claim 3 , wherein the first portion is positioned on the first segment and the sleeve portion is positioned on the second segment.5. The system of claim 4 , wherein the locking mechanism engages the swivel joint by coupling the first portion and the sleeve portion.6. The system of claim 5 , wherein the locking mechanism is selected from a group consisting of a mechanical system claim 5 , an electrical system claim 5 , and a magnetic system.7. The system of claim 3 , wherein the first portion comprises a latch receptacle;wherein the sleeve portion comprises a latch; and wherein the latch locks into the latch receptacle when the swivel joint is engaged.8. The system of claim 1 , wherein the coiled tubing is directed downhole through an injector head; and wherein the locking mechanism engages the swivel joint when the first segment and the second segment pass through the injector head.9. The system of claim 1 , wherein the swivel joint is equipped with a cleaning device; ...

Downhole Movable Joint Tool

A downhole tool operable to connect within a downhole tool string. The downhole tool may include a first sub, a second sub, and a movable joint movably connecting the first sub and the second sub to facilitate relative angular movement between the first sub and the second sub. The downhole tool may be operable to connect together a first portion of the tool string and a second portion of the tool string and facilitate relative angular movement between the first portion of the tool string and the second portion of the tool string when the downhole tool is connected within the tool string.

OIL AND GAS ZIPPER MANIFOLD

A fluid conduit communicates fluid between a zipper leg and an oil and gas wellhead. The fluid conduit may be completely flexible, completely rigid, or partially flexible and partially rigid. The fluid conduit is coupled to the wellhead via a first flow block. The first flow block may include a first downwardly angled surface through which a first downwardly angled flow passage extends and to which a first end portion of the fluid conduit is connected. Similarly, the fluid conduit is coupled to the zipper leg via a second flow block. The second flow block may include a second downwardly angled surface through which a second downwardly angled flow passage extends and to which the fluid conduit is connected. 1. A system , comprising:one or more zipper legs, each including a first flow block;one or more wellheads, each including a second flow block; andone or more first fluid conduits, each connecting the first flow block of one the zipper leg(s) to the second flow block of one of the wellhead(s);wherein: 'at least a portion of the first fluid conduit connected to the first flow block of the at least one of the zipper leg(s) is flexible;', '(i) at least one of the zipper leg(s) includes a first swivel assembly; and'} 'at least a portion of the first fluid conduit connected to the second flow block of the at least one of the wellhead(s) is flexible;', '(ii) at least one of the wellhead(s) includes a second swivel assembly; and'}or(iii) both (i) and (ii).2. The system of claim 1 , wherein (iii).3. The system of claim 1 , wherein (ii).4. The system of claim 1 , wherein (i).5. The system of claim 4 , wherein the at least one of the zipper leg(s) is supported by a skid including legs each having an adjustable length.6. The system of claim 1 , wherein the one or more zipper legs comprise first and second zipper legs;wherein a second fluid conduit is connected between the first and second zipper legs; andwherein the second fluid conduit is supported by a stand including legs ...

UNIVERSAL JOINT

A universal joint assembled in a drill string transfers torque between two components where the shafts of the components are not completely aligned. The universal joint includes two members each with pin connections on one end and axially extending arms on the other end. The axially extending arms intermesh when the members are assembled defining a closed cavity between the arms. The cavity retains a ball bearing held between two seats. The universal joint when assembled to portions of the drill string at the pins on each end transfer torque by intermeshing of the teeth. Axial force is transferred through the seats holding the ball bearing. 1. A universal joint for a downhole drill string comprises:an upper joint member with a first axis and longitudinally extending arms; anda lower joint member with a second axis and longitudinally extending arms;where the arms of the of the upper joint member engage the arms of the lower joint member to transmit torque, the upper joint member pivots about the lower joint member at a pivot point, and the first axis and second axis coincide at the pivot point.2. The universal joint of where the universal joint includes a ball bearing about which the upper and lower joint members pivot.3. The universal joint of where the upper joint member and the lower joint member each includes a bearing face to contact the ball bearing.4. A universal joint for downhole drill strings comprising an upper joint member with longitudinally extending arms claim 2 , a lower joint member with longitudinally extending arms claim 2 , the arms of the upper and lower joint members being intermeshed with each other claim 2 , and a ball bearing being confined within the arms of the upper and lower joint members.5. The universal joint of including an upper bearing seat mounted to the upper joint member and a lower bearing seat mounted to the lower joint member claim 4 , where the upper and lower bearing seats contact the ball bearing on opposite sides.6. The ...

Articulating Assembly For Transmitting Rotation Between Angularly Offset Members

An articulating assembly, including a first member having a first end, a second member, and a first coupling shaft engaged with the first end of the first member and with the second member, wherein the first coupling shaft has a first coupling shaft axis, the first coupling shaft is rotatable relative to the second member about the first coupling shaft axis, wherein the first member is rotatable relative to the first coupling shaft about a swivel axis, and wherein the swivel axis is perpendicular to the first coupling shaft axis, thereby providing an articulating coupling between the first end of the first member and the second member. The articulating assembly may further include an articulating coupling between a second end of the first member and a third member. 1. An articulating assembly comprising:(a) a first member having a first end, wherein the first end of the first member comprises a first thrust bearing surface;(b) a second member, wherein the second member comprises a second thrust bearing surface, and wherein the first end of the first member is received within the second member so that the first thrust bearing surface engages with the second thrust bearing surface; and(c) a first coupling shaft engaged with the first end of the first member and with the second member, wherein the first coupling shaft has a first coupling shaft axis, wherein the first coupling shaft is rotatable relative to the second member about the first coupling shaft axis, wherein the first member is rotatable relative to the first coupling shaft about a swivel axis, and wherein the swivel axis is perpendicular to the first coupling shaft axis.2. The articulating assembly as claimed in wherein one of the first end of the first member and the first coupling shaft defines an arcuate flange claim 1 , wherein the other of the first end of the first member and the first coupling shaft defines an arcuate groove claim 1 , and wherein the arcuate flange is received within the arcuate ...

RISERLESS WELL SYSTEMS AND METHODS

A riserless well abandonment system includes a surface vessel, a first mast extending from the surface vessel, a second mast extending from the surface vessel, wherein the second mast is spaced from the first mast, a running tool extending from the first mast, wherein a subsea intervention device is coupled to the running tool, and a concentric drill string extending from the second mast, wherein the concentric drill string includes an inner drill pipe disposed within an outer drill pipe. 1. A riserless well abandonment system , comprising:a surface vessel;a first mast extending from the surface vessel;a second mast extending from the surface vessel, wherein the second mast is spaced from the first mast;a running tool extending from the first mast, wherein a subsea intervention device is coupled to the running tool; anda concentric drill string extending from the second mast, wherein the concentric drill string comprises an inner drill pipe disposed within an outer drill pipe.2. The riserless well abandonment system of claim 1 , wherein the subsea intervention device comprises:a ram blowout preventer configured to seal a bore of the subsea intervention device;an annular blowout preventer; anda rotating control device configured to seal against the concentric drill string when the drill string extends through the subsea intervention device and is rotating relative to the subsea intervention device.3. The riserless well abandonment system of claim 1 , wherein the concentric drill string comprises an inner drill pipe disposed within an outer drill pipe.4. The riserless well abandonment system of claim 3 , wherein the subsea intervention device is coupled to a wellhead disposed on the sea floor.5. The riserless well abandonment system of claim 3 , wherein:when the concentric drill pipe extends into a borehole extending from the wellhead, an inlet fluid flowpath is formed between an annulus disposed between the inner drill pipe and the outer drill pipe and the borehole; ...

CATCHER DEVICE FOR A DOWNHOLE TOOL

A downhole catcher device comprises a catching mechanism which is configured to be transferable between a first mode and a second mode. The catching mechanism is further configured for passing by a first operation element if the catching mechanism is in the first mode and for catching a second operation element if the catching mechanism is in the second mode. The transfer between the first and the second mode is triggered (or effected) by a downhole tool which is operated by the second operation element. 120-. (canceled)21. A downhole catcher device , the catcher device comprising:a catching mechanism being transferable between a first mode and a second mode;the catching mechanism being configured for passing by a first operation element if the catching mechanism is in the first mode; andthe catching mechanism being configured for catching a second operation element if the catching mechanism is in the second mode.22. The catcher device according to ; further comprising a first coupling element for coupling the catching mechanism to a second coupling element of a downhole tool located upstream the catching mechanism claim 21 , wherein a movement of the first coupling element transfers the catching mechanism from the first mode to the second mode claim 21 , in particular wherein the first coupling element forms at least part of a swivel coupling.23. The catcher device according to claim 22 , the catching mechanism comprising a diverter; the diverter being movable from a first position into a second position wherein the first position corresponds to the first mode and the second position corresponds to the second mode; wherein the movement of the first coupling element is an axial movement in a first direction and wherein a movement of the diverter from the first position to the second position includes a rotational movement crosswise the axial movement.24. The catcher device according to claim 23 , further comprising a guiding mechanism which translates the axial ...

LARGE BORE ASSEMBLY AND SPHERICAL SWIVEL JOINT

A zipper stack is connected to a wellhead by way of a single straight-line pipe connection. A manifold assembly with high- and low-pressure lines feeding into one or more fluid lines with a large internal bore diameter supplies fracturing fluid to the zipper stack, which in turn supplies the fracturing fluid to the wellhead. A spherical swivel joint with multiple bearings may be used to the connect various piping and fluid lines disclosed herein. 1. A spherical swivel joint , comprising:a first yoke comprising a first flange and defining a first fluid passage;a first bearing coupled to the first yoke;a second yoke comprising a second flange and defining a second fluid passage;a second bearing coupled to the second yoke; anda crossover spool coupled to the first bearing and the second bearing, the crossover spool defining a third fluid passage that creates an aggregate fluid pathway comprising the first fluid passage, the second fluid passage, and the third fluid passage.2. The spherical swivel joint of claim 1 , wherein the crossover spool is movable through movement of the first bearing.3. The spherical swivel joint of claim 2 , wherein the crossover spool is free to move at least one of the x- claim 2 , y- claim 2 , or z-directions based on coupling to the first bearing.4. The spherical swivel joint of claim 3 , wherein the crossover spool is movable up to seven degrees relative to a longitudinal axis of the first yoke.5. The spherical swivel joint of claim 1 , wherein the first bearing is positioned inside a cylindrical bearing housing.6. The spherical swivel joint of claim 1 , further comprising one or more longitudinally extending flange connectors extending from the first flange for mating with reciprocal flange receptacles claim 1 , thereby connecting the first flange to external flow iron components.7. The spherical swivel joint of claim 1 , wherein the flange is configured to be threadably connected to external flow iron components.8. The spherical swivel ...

METHODS AND SYSTEMS FOR REDUCING DRAG AND FRICTION DURING DRILLING

Embodiments disclosed herein describe a rotating flow coupler that is configured to couple multiple sections of a casing for a horizontal well, wherein the rotating flow coupler is configured to rotate relative to the casing allowing an additional degree of freedom for equipment being lowered into the well. This may allow for equipment such as coil tubing, drilling string, casings strings, etc. to reach a total distance of deeper laterals. 1. A rotating flow coupler configured to couple multiple sections of casing comprising:an outer tool with an outer diameter configured to be positioned proximate to sidewalls of a borehole;an inner tool configured to be positioned adjacent to an inner diameter of the outer tool, the inner tool configured to rotate relative to the outer tool;a first bearing positioned between the inner tool and the outer tool.2. The rotating flow coupler of claim 1 , wherein the outer tool includes a shoulder that extends from the inner diameter of the outer tool towards the inner tool claim 1 , the shoulder being configured to receive a load from the first bearing.3. The rotating flow coupler of claim 1 , wherein the outer tool is configured to be fixed in place while the inner tool rotates based on a load applied to the multiple sections of the casing.4. The rotating flow coupler of claim 1 , wherein a first distance across an inner diameter of the inner tool is substantially equal to that of a second distance across an inner diameter of the multiple sections of the casing.5. The rotating flow coupler of claim 1 , wherein a first distance across an inner diameter of the inner tool is smaller than that of a second distance across an inner diameter of the multiple sections of the casing.6. The rotating flow coupler of claim 1 , wherein a third distance across the outer diameter of the outer tool is greater than that of a fourth distance across an outer diameter of the multiple sections of the casing.7. The rotating flow coupler of claim 1 , further ...

Single Line Apparatus, System, And Method For Fracturing A Multiwell Pad

A system for distributing pressurized fluid during wellbore operations can include a pressure vessel having a fluid inlet and a fluid outlet. The system can also include a conduit rotatably connected to the fluid outlet of the pressure vessel for coupling to one or more wellbores. Also, a method for distributing pressurized fluid during wellbore operations can include receiving pressurized fluid in a pressure vessel. The method can also include distributing to one or more wellbores the pressurized fluid from the pressure vessel through a conduit rotatably connected to the pressure vessel. 1. A system for distributing pressurized fluid during wellbore operations , the system comprising:a pressure vessel having a fluid inlet and a fluid outlet; anda conduit rotatably connected to the fluid outlet of the pressure vessel for coupling to one or more wellbores.2. The system of claim 1 , wherein the fluid inlet is fixedly coupled to the pressure vessel.3. The system of claim 1 , wherein the pressure vessel is mounted on a platform.4. The system of claim 1 , wherein the pressure vessel rotates relative to the fluid inlet.5. The system of claim 1 , further comprising:a pressurized fluid pump coupled to the fluid inlet, wherein the pressurized fluid pump delivers pressurized fluid through the pressure vessel and the fluid outlet to the one or more wellbores.6. The system of claim 1 , wherein the conduit has an inverted U shape.7. The system of claim 1 , wherein the one or more wellbores comprises a tree line assembly that couples to the conduit claim 1 , wherein the tree line assembly is movable relative to a remainder of the one or more wellbores.8. The system of claim 7 , wherein the tree line assembly of each wellbore comprises a horizontal leg pipe claim 7 , a down leg pipe claim 7 , and a fracturing tree.9. The system of claim 8 , wherein the tree line assembly further comprises a first rotating joint disposed between the horizontal leg pipe and the down leg pipe.10. The ...

BI-DIRECTIONAL CV-JOINT FOR A ROTARY STEERABLE SYSTEM

An example downhole apparatus includes a drive shaft with a longitudinal axis, a spherical portion that extends radially from the longitudinal axis, and first and second interfacial surfaces proximate the spherical portion. An outer housing is positioned at least partially around the spherical portion. A radial bearing may be between the spherical portion and the outer housing and coupled to the outer housing. The radial bearing may comprise first and second interfacial surfaces in contact with the respective first and second interfacial surfaces of the drive shaft to transmit or receive torque in corresponding first and second rotational directions. A first axial bearing is coupled to the outer housing and in contact with a first end of the spherical portion to axially secure the drive shaft with respect to the outer housing. 1. A downhole apparatus for drilling operations , comprising:a drive shaft with a longitudinal axis, a spherical portion extending radially from the longitudinal axis, and first and second interfacial surfaces proximate the spherical portion;an outer housing at least partially around the spherical portion;a radial bearing coupled to the outer housing between the spherical portion and the outer housing and comprising first and second interfacial surfaces in contact with the respective first and second interfacial surfaces of the drive shaft to transmit or receive torque in corresponding first and second rotational directions; anda first axial bearing coupled to the outer housing and in contact with a first end of the spherical portion to axially secure the drive shaft with respect to the outer housing.2. The apparatus of claim 1 , wherein the first interfacial surface of the drive shaft is positioned on a first oscillating disk coupled to the drive shaft claim 1 , and the second interfacial surface of the drive shaft is positioned on a second oscillating disk coupled to the drive shaft.3. The apparatus of claim 2 , wherein the first interfacial ...

Universal Joint

A universal joint assembled to a drill string transfers torque and axial force between two components along a longitudinal axis where the shafts of the components are not completely aligned. The universal joint includes axially spaced members joined by transversely spaced links. As the joint rotates the links move to accommodate misalignment between the drill string components and the connected members. 1. A universal joint for transmitting torque from one shaft to another shaft , the joint comprising:a first member for coupling with a first shaft, the first member having a first axis of rotation coincident with the axis of rotation of the first shaft when connected to the first shaft;a second member for coupling with a second shaft, the second member, when coupled with the second shaft, having a second axis of rotation coincident with the axis of rotation of the second shaft;a spacer for separating the first and second shafts in a spaced relationship; anda plurality of links, each comprised of a first and a second end, the first end of each of the plurality of links being coupled to the first member at a position displaced radially from the first axis, and the second end being connected to the second member and a position displaced radially form the second axis.2. The universal joint of claim 1 , wherein each of the plurality of links is connected to at least one of first and second member with a resilient terminating member.3. The universal joint of claim 1 , wherein the first and the second members each have fixed positions relative to the first and second shafts claim 1 , respectively.4. The universal joint of claim 1 , wherein the second member is comprised of a sleeve that slides axially with respect to the second shaft but rotates with the shaft claim 1 , and is resiliently biased away from the first member.5. The universal joint of claim 1 , wherein the spacer has at least one set of complementary bearing surfaces for permitting rotation and articulation of ...

Universal joint for downhole motor drive

A constant velocity universal joint is assembled as a crown ball meshed within a housing socket for rotation about respective rotational axes. The outside diameter of the crown ball is greater than the inside diameter of the socket. A plurality of channels, equally spaced around the crown ball perimeter are cut into the crown ball surface generally along or parallel with the crown ball drive axis. An arcuate cup is cut into each crown ball channel to confine a respective torque transfer element. A number, corresponding to the number of crown ball channels, of partial cylinder channels are cut into the inside surface of the housing socket. One of opposite side walls for each housing channel is given an arcuate radius corresponding to that of the force transfer elements. Ridges between adjacent crown ball channels mesh with ridges between adjacent housing socket channels. Torque transfer elements confined within said crown ball cups engage the partial cylinder wall of the housing channels to transfer drive forces between the crown ball and socket housing through a departure angle between the respective rotational axes.

RADIAL DRILLING LINK TRANSMISSION AND FLEX SHAFT PROTECTIVE COVER

Systems and methods for performing a radial drilling operation using a shaft are disclosed. The shaft can be flexible and can be made of a series of links, each of which can have a hexagonal or other suitable shape to impart a torque along the linkage. A cable system can be run through the middle of the links and can be resiliently tensioned to permit a different degree of flexure according to the amount of tension in the cable and resilient member. Accordingly, the shaft can be rigid, selectively permitted to flex, or can be brought back to a straight or at least a less-bent position. 1. A system for deploying a shaft , comprising:a support shaft configured to be operatively coupled to a motor to rotate the support shaft;a motor nose coupled to the support shaft, the motor nose having a first coupling and a second coupling, wherein the first coupling is radially inward of the second coupling;a tool shaft coupled to the first coupling and being configured to rotate with the support shaft and the motor nose, the tool shaft having an outer diameter; anda protective sleeve coupled to the second coupling on the motor nose, wherein the protective sleeve is rigid and has an interior diameter slightly larger than the outer diameter of the tool shaft, wherein the tool shaft is configured to rest within the protective sleeve such that the protective sleeve prevents the tool shaft from flexing, and wherein the protective sleeve is configured to selectively retract into the motor nose to reveal the tool shaft.2. The system of wherein the support shaft defines an axial direction claim 1 , and wherein the first coupling is movable relative to the second coupling along the axial direction.3. The system of claim 1 , further comprising a drill bit coupled to the tool shaft and being configured to rotate under power of the motor.4. The system of wherein the protective sleeve is threadably coupled to the motor nose.5. The system of wherein the protective sleeve is threadably ...

Drill String Apparatus with Integrated Annular Barrier and Port Collar, Methods, and Systems

A drill string apparatus includes an upper casing section having a port collar. The port collar provides a controllable opening from an interior of the upper casing section to an annulus around the upper casing section. A lower casing section is coupled to the upper casing section through a swivel. The lower casing section includes an external casing packer and a casing pad coupled to an external portion of the lower casing section. The external casing packer is expandable to an annulus around the lower casing section before a cement operation to avoid cement loss circulation to weak formation below the packer. Methods and systems are also disclosed. 1. A directional drill string apparatus , comprising:an upper casing section comprising a port collar that provides an opening from the upper casing section to an annulus around the upper casing section; and an annular barrier coupled to an external portion of the lower casing section, wherein the annular barrier is expandable to an annulus around the lower casing section prior to cementing; and', 'a casing pad coupled to an external portion of the lower casing section., 'a lower casing section coupled to the upper casing section through a swivel, the lower casing section comprising2. The drill string apparatus of claim 1 , further comprising a rotary steerable system (RSS) and RSS housing disposed within the lower casing section.3. The drill string apparatus of claim 2 , wherein the RSS housing is coupled to the lower casing with at least one set of latches such that rotational movement between the RSS and the lower casing section is impeded.4. The drill string apparatus of claim 3 , wherein the lower casing section is configured to be stationary while the upper casing section is configured to rotate with the port collar open during the cementing.5. The drill string apparatus of claim 4 , further comprising a drill bit coupled to an internal shaft of the RSS.6. The drill string apparatus of claim 5 , further comprising ...

Constant-Velocity Joint With Surface Contact Forks

A constant-velocity joint can have three pieces: a yoke, a first adaptor, and a second adaptor. Grooves on opposite sides of the yoke can receive forks of the adaptors and be perpendicular to one another. The yoke can have a guide surface within each groove so that a matching following surface on the fork of the adaptor can engage the guide surface to guide the movement of the fork within the groove. The adaptors may pivot within the grooves such that surfaces of flanks of the forks remain engaged or provide a consistent amount of surface contact with flanks of the groove throughout the pivot of the forks. Torque can be transferred through the engaged flanks as the joint is used to convert eccentric rotation to concentric rotation. 1. A constant-velocity joint comprising:a yoke comprising a plurality of grooves, the plurality of grooves including first grooves in a first side of the yoke and second grooves in a second side of the yoke;a first adaptor comprising a plurality of first forks, each respective first fork having at least one first torque surface received in a respective of the first grooves for transferring torque from the first adaptor to the yoke; anda second adaptor comprising a plurality of second forks, each respective second fork having at least one second torque surface received in a respective of the second grooves for transferring torque from the yoke to the second adaptor.2. The constant-velocity joint of claim 1 , wherein each respective first groove has at least one first guide surface and each respective first fork has at least one first following surface slidable along the at least one first guide surface of the respective first groove; andwherein each respective second groove has at least one second guide surface and each respective second fork has at least one second following surface slidable along the at least one second guide surface of the respective second groove.3. The constant-velocity joint of claim 2 , wherein at one first guide ...

Tension-Set Tieback Packer

An apparatus for supporting tubing in casing includes a setting tool and a liner top packer, which can be used for tieback. A setting slip is disposed uphole of a packing assembly on the packer and is movable from a retracted to an extended state engaging the casing. The setting tool has a temporary connection to the packer and has a pack-off that seals the tool in the packer but allows for movement. After running downhole, the temporary connection of the setting tool to the packer is disconnected, and the setting slip is set in the casing by moving the setting tool in an uphole direction. To set the packing assembly, the packer is moved in the uphole direction by engaging the setting tool with the pack-off and compressing the packing element (e.g., packing element and opposing cones and slips) against the set setting slip. Eventually, the setting tool is disconnected from the packer by disengaging the pack-off. 1. An apparatus for supporting tubing in casing of a borehole , the apparatus comprising:a packer having a housing and a packing element, the housing defining a bore and coupled to the tubing extending downhole therefrom, the packing element disposed on the housing and being settable from an unpacked state to a packed state in the casing; anda setting tool for setting the packer in the casing and being retrievable therefrom the set packer, the setting tool having an inner mandrel and an outer mandrel, the outer mandrel having at least one setting slip being movable from a retracted state away from the casing to an extended state toward the casing, the outer mandrel having a first rotatable connection to the inner mandrel and permitting the at least one setting slip to be in the retracted state, the inner mandrel having a second rotatable connection to the housing of the packer,the inner mandrel rotated with first rotation relative to the outer mandrel releasing the first rotatable connection and permitting extension of the at least one setting slip for ...

ORIENTATION VERIFICATON DEVICES

An orientation verification tool permits an operator to confirm an orientation of one or more perforating charges in a perforating gun assembly when the perforating charges are not readily visible for inspection. The orientation verification tool includes an end fixture rotationally coupled at a longitudinal end of a charge carrier disposed within a tubular gun body. The end fixture includes a visual indicator of the orientation of the perforating charges on a longitudinal end face thereof. The visual indicator may include a plurality of hatch marks arranged at regular intervals around the end fixture, and each hatch mark may be identified by a specific angular identifier so that the hatch mark located at a reading location will identify the angular orientation of the perforating charges. 1. A perforating gun apparatus , comprising:a charge carrier defining a rotational axis;at least one perforating charge coupled to the charge carrier, the at least one perforating charge defining a lateral discharge direction;an end fixture coupled to a longitudinal end of the charge carrier and rotationally coupled to the charge carrier about the rotational axis, the end fixture defining a longitudinal end face with a visual reference indicator marked thereon in alignment with the lateral discharge direction of the at least one perforating charge.2. The apparatus of claim 1 , wherein the longitudinal end face of the end fixture further comprises a plurality of visual indicators radially spaced around a perimeter thereof.3. The apparatus of claim 2 , wherein the plurality of visual indicators includes at least one numerical indicator corresponding to an angular position of the at least one numerical indicator from the reference indicator.4. The apparatus of claim 1 , further comprising a plurality of fasteners coupled to one of the end fixture and the charge carrier in an asymmetrical array claim 1 , and wherein the other one of the end fixture and the charge carrier includes a ...

Axial face seal system

A technique facilitates enhanced sealing capability in a space saving format when utilizing a plurality of uniquely constructed seals. As a result, the seals are useful in swivels and other types of structures to provide secure sealing between seal surfaces while reducing the overall seal area. Each seal comprises a body having a seal base combined with lips which may be activated when the activation fluid is supplied under pressure. In swivel applications, the seals may be constructed in a vertical orientation as axial face seals. The vertical orientation of the seals enables construction of the swivel with a reduced cross-section and thus a reduced hydraulic loading.

FRACTURING MANIFOLD SYSTEMS AND METHODS

A fracturing system is provided. In one embodiment, the fracturing system includes a fracturing manifold for routing fracturing fluid to multiple wells. The fracturing manifold can be coupled via fluid conduits to fracturing trees installed at the wells. In some cases, each fracturing tree that is coupled to the fracturing manifold is coupled by at least one rigid fluid conduit. The fracturing manifold can include a trunk line that provides fracturing fluid to multiple outlet branches, which can include valves for controlling flow of fracturing fluid to wells downstream of the valves. Additional systems, devices, and methods are also disclosed. 1. A system comprising:a fracturing manifold;a plurality of fracturing trees; anda plurality of fluid conduits coupled between the fracturing manifold and the plurality of fracturing trees to enable receipt of fracturing fluid by the plurality of fracturing trees from the fracturing manifold, wherein each fracturing tree of the plurality of fracturing trees coupled to the fracturing manifold is coupled to the fracturing manifold by at least one rigid fluid conduit of the plurality of fluid conduits.2. The system of claim 1 , comprising a first goat head at the fracturing manifold and a second goat head at a fracturing tree of the plurality of fracturing trees claim 1 , wherein the first goat head and the second goat head are in fluid communication with each other.3. The system of claim 1 , wherein the fracturing manifold includes:a shared trunk conduit for routing fracturing fluid to multiple fracturing trees of the plurality of fracturing trees; andoutlet branches for routing fracturing fluid from the shared trunk conduit to individual fracturing trees of the multiple fracturing trees.4. The system of claim 3 , wherein the outlet branches of the fracturing manifold include valves to individually control flow of fracturing fluid from the shared trunk conduit to the multiple fracturing trees.5. The system of claim 4 , wherein ...

Methods for Estimating Wellbore Gauge and Dogleg Severity

Methods for measuring wellbore gauge and dogleg severity are disclosed. The methods include deploying a downhole tool in a subterranean wellbore. The downhole tool includes first and second axially spaced stabilizers deployed on at least one tool body section coupled to a universal joint. The method for measuring wellbore gauge further includes measuring first and second axial directions of the tool body section when the universal joint is tilted in corresponding first and second cross-axial directions and processing the first and second measured axial directions to estimate the wellbore gauge. The method for measuring dogleg severity further includes measuring first and second tilt angles of the universal joint when the universal joint is tilted in corresponding first and second cross-axial directions and then processing the first and second measured tilt angles to estimate the dogleg severity.

ROTATING AND RECIPROCATING SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus wherein a rotating and reciprocating swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections with the mandrel of the swivel being comprised of double box end joints and using double pin end subs to connect a plurality of such mandrel joints together. 1. A method of using a reciprocating swivel in a drill or work string , the method comprising the following steps:(a) positioning a rotating and reciprocating tool to an annular blow out preventer, the tool comprising a mandrel and a sleeve, the sleeve being reciprocable relative to the mandrel and the mandrel including at least one joint having double box ends with the joint being severable by a ram blow out preventer, the sleeve having two spaced apart sealing units, the swivel including an interstitial space between the sleeve and the mandrel with first and second spaced apart sealing units each sealing the interstitial space;(b) after step “a”, having the annular blow out preventer close on the sleeve; and(c) after step “b”, causing relative longitudinal movement between the sleeve and the mandrel, wherein in step “a” the mandrel includes two double box end joints which are connected by a double pin end sub, and in step “c” when the double pin end sub is at the same longitudinal position as the first sealing unit, the first sealing unit loses its seal of the interstitial space, but the second sealing keeps its seal of the interstitial space.2. The method of claim 1 , wherein after the double pin end sub passes by the first sealing unit claim 1 , the first sealing unit regains its seal of the interstitial space.3. The method of claim 2 , wherein when the double pin end sub is at the same longitudinal position as the second sealing unit claim 2 , the second sealing unit loses its seal of the interstitial space claim 2 , but the first sealing keeps its seal of the interstitial space.4. The ...

ROTARY LOCKING SUB FOR ANGULAR ALIGNMENT OF DOWNHOLE SENSORS WITH HIGH SIDE IN DIRECTIONAL DRILLING

Adjustment of the angle of a bent sub or other steering feature in a drill string relative to a reference angle of a downhole sensor is facilitated by a rotatable coupling between the bent sub and the sensor. The rotatable coupling may be rotated to align the high side with a reference indicium and locked at the set angle. Rows of ceramic balls retained in circumferential channels may be provided to permit rotation while carrying tensile and compressional forces. Calibration of the sensor is facilitated and opportunities for certain measurement errors are eliminated. An embodiment provides a mechanism for locking the rotatable coupling at a desired angle. The embodiment comprises a ring with teeth that engage a downhole portion of the coupling and depressions that engage an uphole portion of the coupling. 1. A drill string section comprising:a first part having a first through bore;a second part having a second through bore;a rotational locking mechanism operable to selectively permit or prevent relative rotation of the first and second parts; anda locating feature in the first bore of the first part for holding a downhole probe at a fixed rotation angle in the first bore; the rotational locking mechanism comprises a ring that is slidably and non-rotatably mounted on the first part;', 'the ring comprises engagement features configured to engage corresponding engagement features on the second part;', 'the rotational locking mechanism has a rotatable configuration in which the engagement features of the ring do not engage the engagement features of the second part and the first part is rotatable relative to the second part;', 'the rotational locking mechanism has a locked configuration in which the engagement features of the ring engage the engagement features of the second part and the first part is not rotatable relative to the second part; and', 'the rotational locking mechanism comprises a locking mechanism for holding the rotational locking mechanism in the ...

SYSTEMS AND METHODS FOR REDUCING THE EFFECT OF BOREHOLE TORTUOSITY ON THE DEPLOYMENT OF A COMPLETION ASSEMBLY

A completion system for running in a directional wellbore includes a plurality of tubular members mechanically secured in-line to form a production tubular. One or more isolation packers are positioned in-line with the tubular members. A lower completion guide is located at a downhole end of the production tubular and a hanger assembly located at an uphole end of the production tubular. One or more of the tubular members includes a flexible pipe joint having: a base multilayered flexible tubular member; a first weave layer, the first weave layer being helically wrapped in a first direction around an outer diameter of the base multilayered flexible tubular member; a second weave layer, the second weave layer being helically wrapped in a second direction around an outer diameter of the first weave layer; and an outer tubular layer. 1. A completion system for running in a directional wellbore , the completion system including:a plurality of tubular members mechanically secured in-line to form a production tubular;one or more isolation packers positioned in-line with the tubular members;a lower completion guide located at a downhole end of the production tubular; anda hanger assembly located at an uphole end of the production tubular; where a base multilayered flexible tubular member;', 'a first weave layer, the first weave layer being helically wrapped in a first direction around an outer diameter of the base multilayered flexible tubular member;', 'a second weave layer, the second weave layer being helically wrapped in a second direction around an outer diameter of the first weave layer; and', 'an outer tubular layer., 'one or more of the tubular members includes a flexible pipe joint, the flexible pipe joint having2. The completion system of where the base multilayered flexible tubular member includes an inner liner member and a reinforcing member circumscribing the inner liner member.3. The completion system of claim 1 , where the completion system includes at least ...

Dual clutch system for travel joint

A dual clutch travel joint system includes an inner-mandrel and an outer-mandrel. The inner-mandrel includes a first connector on a downhole portion of the inner-mandrel and a second connector on an uphole portion of the inner-mandrel. The outer-mandrel includes a third connector that is positionable to mate with the first connector to apply torque to the inner-mandrel while the inner-mandrel is in a tension arrangement with the outer-mandrel within a wellbore. Additionally, the outer-mandrel includes a fourth connector positionable to mate with the second connector to apply torque to the inner-mandrel while the inner-mandrel is in a compression arrangement with the outer-mandrel within the wellbore.

HIGH PRESSURE SWIVEL JOINT

A high pressure swivel joint used in pipe assemblies transferring high pressure fluid. The swivel joint comprises a first pipe section and a sleeve-like second pipe section. The first pipe section is inserted into the second pipe section and the sections are relatively rotatable. A wear ring is positioned. within a recess formed in the inner wall of the first pipe section. A second wear ring is positioned within a recess formed in the inner wall of the second pipe section. 1. A swivel joint , comprising:a tubular first connector having a hollow end within which an internal face is formed and a first longitudinal axis;a tubular second connector having an end upon which an external face is formed and a second longitudinal axis, the end of the second connector received within the end of the first connector such that the first and second axes coincide, such that the connectors are relatively rotatable about the coincident axes, and such that the faces engage at an interface extending within a plane normal to the axes;an internal bore extending through each of the joined first and second connectors;a first annular recess formed within the internal bore and at a position upstream from the interface;a first zone of hardened wear material situated within the first recess; andin which the hardened wear material is press-fit within the first recess such that at least a portion of the hardened wear material directly engages a wall or walls defining the first recess.2. The swivel joint of claim 1 , further comprising:a second annular recess formed within the internal bore and at a position downstream from the interface; anda second zone of hardened wear material situated within the second recess;in which the hardened wear material is press-fit within the second recess such that at least a portion of the hardened wear material directly engages a wall or walls defining the second recess.3. The swivel joint of claim 1 , further comprising:a first seal interposed between the second ...

Method And Apparatus For String Access Or Passage Through The Deformed And Dissimilar Contiguous Walls Of A Wellbore

Method and apparatus for providing access to a lower end wellbore through an impasse using an circumferential adaptable apparatus and downhole devices to pilot a tool string through an existing obstructive frictional or restricted passageway with dissimilar well bore walls, wherein piloting a tool string may comprise displacing debris within and/or deforming its proximally circular and/or deformed bores or traversing an obstructive passageway therebetween, and whereby various downhole devices may be incorporated, deployed and oriented relative to a proximal axis or proximally contiguous wall, using the expandable and collapsible members of the present invention engaged about a plurality of shafts, usable to pilot the tool string through a conventional impasse or restriction of said walls of said dissimilar contiguous passageways. 1111910. A method ( , A-AE) of using a tool string and a downhole device with a circumferential adaptable apparatus to urge access or passage through an obstructive dissimilar contiguous passageway () of a subterranean well bore () , said method comprising the steps of:{'b': 8', '8', '8', '17', '6', '6', '6', '2', '2', '2', '3', '3', '3', '11', '12', '19', '20', '24', '27', '28, 'using the tool string (A-AE) comprising a deployment string () with a lower end coiled string compatible connector () engaged to an upper end shaft segment of a plurality of movable shaft segments (, A-AE) interoperable with at least one circumferential adaptable apparatus (, A-AE) and at least one downhole device (, A-AE, , , , , , , ) deployed or removed through an upper end of the subterranean well bore and into or out of a lower end of said well bore to urge access or passage through the obstructive dissimilar contiguous passageway;'}{'b': 7', '7', '7', '4', '4', '4', '5', '5', '5', '18, 'selectively arranging said tool string to use said at least one circumferential adaptable apparatus by engaging an axial pivotal member (, A-AE) and an associated flexible ...

MULTI-FUNCTION TOOL FOR A DRILLING RISER

Embodiments of the present disclosure include a multi-function tool that includes a positioning assembly configured to move with a first degree of freedom of rotation, a second degree of freedom of axial movement in a first direction, and a third degree of freedom of axial movement in a second direction crosswise to the first direction, a cutting tool configured to selectively couple to the positioning assembly, and a measurement tool configured to selectively couple to the positioning assembly. 1. A multi-function tool , comprising:a positioning assembly configured to move with a first degree of freedom of rotation, a second degree of freedom of axial movement in a first direction, and a third degree of freedom of axial movement in a second direction crosswise to the first direction; andat least one of a cutting tool configured to selectively couple to the positioning assembly, a measurement tool configured to selectively couple to the positioning assembly, or a combination thereof, wherein the cutting tool comprises a drive configured to move the cutting tool with a fourth degree of freedom of rotation, and wherein the measurement tool is configured to measure a surface of a tubing assembly to determine whether the surface meets target tolerance specifications.2. The multi-function tool of claim 1 , comprising a mounting base configured to selectively couple the positioning assembly to an end portion of the tubing assembly claim 1 , wherein the multi-function tool is configured to cut or measure at least one portion of the tubing assembly.3. The multi-function tool of claim 2 , wherein the mounting base is configured to couple the multi-function tool across a central bore of a main tubing of the tubing assembly.4. The multi-function tool of claim 2 , wherein the end portion is a flange claim 2 , the tubing assembly is a riser segment of a drilling riser claim 2 , and the tubing assembly comprises a main tubing and a plurality of auxiliary tubings.5. The multi- ...

SWIVEL JOINT FOR OILFIELD PUMPING STIMULATION

A swivel joint comprises a tubular female member which is rotatably connected to a tubular male member. The female member includes a female race portion having an axially extending inner annular recess, a female inner end portion which is formed at an axially inner end of the recess, and a number of inner annular grooves which are formed in the recess coaxially therewith. The male member includes a male race portion having an annular outer surface which is configured to be received in the recess, a male nose portion which is formed at an end of the male race portion, and a number of outer annular grooves which are formed on the outer surface coaxially therewith. The male race portion is positioned in the female race portion such that the male nose portion is located adjacent the female inner end portion and each outer groove is aligned with a corresponding inner groove to thereby define a number of annular bearing races within which a plurality of balls are received to thereby rotatably connect the male member to the female member. The swivel joint includes a first primary seal which is positioned between the male nose portion and the female inner end portion, and a second primary seal which is positioned between the male nose portion and the female inner end portion radially outwardly of the first primary seal. The male and female members define a flow bore through the swivel joint which is sealed by the first primary seal and, in the event of a failure of the first primary seal, the second primary seal 1. A swivel joint comprising:a tubular female member which includes a female race portion having an axially extending inner annular recess, a female inner end portion which is formed at an axially inner end of the recess, and a number of inner annular grooves which are formed in the recess coaxially therewith;a tubular male member which includes a male race portion having an annular outer surface which is configured to be received in the recess, a male nose portion ...

SAFETY VALVE COUPLING AND METHOD OF MANUFACTURING VALVE

A valve includes a piston, a flow tube, and a coupling transferring longitudinal movement between the piston and flow tube and enabling rotational movement of the flow tube with respect to the piston. The coupling includes a connector and a thrust sleeve. The connector includes a piston attachment feature and a thrust sleeve attachment feature, the piston attachment feature attached to the piston. The thrust sleeve includes a pocket, the thrust sleeve attachment feature disposed within the pocket. The thrust sleeve includes portions disposed radially interiorly and radially exteriorly of the thrust sleeve attachment feature. 1. A valve comprising:a piston;a flow tube; and a connector having a piston attachment feature and a thrust sleeve attachment feature, the piston attachment feature attached to the piston, and', 'a thrust sleeve having a pocket, the thrust sleeve attachment feature disposed within the pocket, the thrust sleeve including portions disposed radially interiorly and radially exteriorly of the thrust sleeve attachment feature., 'a coupling transferring longitudinal movement between the piston and flow tube and enabling rotational movement of the flow tube with respect to the piston, the coupling including2. The valve of claim 1 , wherein the connector and the thrust sleeve are additively manufactured as a single unit.3. The valve of claim 2 , wherein the connector and thrust sleeve are additively manufactured with a clearance between the thrust sleeve attachment feature and the pocket.4. The valve of claim 1 , wherein the connector and the thrust sleeve are inseparable.5. The valve of claim 1 , wherein the thrust sleeve attachment feature includes a first section and a second section having a longer radial length than the first section claim 1 , and the thrust sleeve includes a pocket having a throat section and a receiving portion claim 1 , the first section disposed in the throat section and the second section disposed in the receiving portion.6. ...

SEAL CONFIGURATION FOR TOP DRIVE SWIVEL APPARATUS AND METHOD

For use with a top drive power unit supported for connection with a well string in a well bore to selectively impart longitudinal and/or rotational movement to the well string, a feeder for supplying a pumpable substance such as cement and the like from an external supply source to the interior of the well string in the well bore without first discharging it through the top drive power unit including a mandrel extending through a sleeve which is sealably and rotatably supported thereon for relative rotation between the sleeve and mandrel. The mandrel and sleeve have flow passages for communicating the pumpable substance from an external source to discharge through the sleeve and mandrel and into the interior of the well string below the top drive power unit. The unit can include a packing injection system and novel seal configuration. 117-. (canceled)18. A top drive swivel insertable into a drill or work string comprising:(a) a mandrel having upper and lower end sections and rotatable with upper and lower drill or work string sections having a drill or work string passage, the mandrel including a longitudinal passage(b) a sleeve having a longitudinal sleeve passage, the sleeve being rotatably connected to the mandrel;(c) a pair of spaced apart packing units between upper and lower end portions of the mandrel and sleeve, the packing units preventing leakage of fluid between the mandrel and sleeve;(d) the sleeve comprising an inlet port(e) the mandrel comprising a plurality of spaced apart radial ports in fluid communication with both the inlet port and the sleeve passage to supply fluid from the inlet port to the sleeve passage and the drill or work string passage in drill or work string sections; and(f) wherein each of the packing units comprise a plurality of packing rings, at least one packing ring in each packing unit being comprised of a rope seal.19. The top drive swivel of claim 18 , wherein each packing unit comprises five packing rings claim 18 , one being ...

Downhole Swivel Tool

The invention provides a swivel tool for use in a wellbore. The tool comprises a tool body and a mandrel which is axially moveable relative to the tool body. The tool also comprises a lock member moveable between a first condition in which the mandrel is rotatably movable relative to tool body and a second condition in which the mandrel and a tool body are rotationally coupled. The lock member is configured to move between the first condition and second condition in response to a mechanical axial force and rotational force on the mandrel. 155-. (canceled)56. A swivel tool for use in a wellbore comprising:a tool body;a mandrel which is axially moveable relative to the tool body;and a lock member moveable between a first condition in which the mandrel is rotatably movable relative to the tool body and a second condition in which the mandrel and the tool body are rotationally coupled;wherein the lock member is configured to move between the first condition and second condition in response to a mechanical axial force and rotational force on the swivel tool.57. The swivel tool according to wherein the tool body is connectable to a downhole apparatus and/or to a downhole string.58. The swivel tool according to wherein the swivel tool is connectable to a drill string above a liner and/or to a drill string above a sand screen apparatus.59. The swivel tool according to wherein the lock member is configured to move between the first condition and second condition in response to tension and right-hand rotation of the mandrel or in response to tension and left-hand rotation of the mandrel.60. The swivel tool according to wherein the swivel tool is configured to be locked by mechanical manipulation of the mandrel or a downhole string connected to the mandrel.61. The swivel tool according to comprising a bearing member wherein the bearing member is located between an inner surface of the tool body and an outer surface of the mandrel claim 56 , and wherein the bearing member is ...

DOWNHOLE TUBING SWIVELS AND RELATED METHODS

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. 1. A downhole tubing swivel comprising:a top sub for connection to a tubing string of a production well, the top sub comprising a first engagement structure;a mandrel comprising a second engagement structure;a coupling to engage both the first engagement structure and the second engagement structure;a housing to cover an internal space of the tubing swivel, between the housing, the top sub, and the mandrel and including the coupling, and to couple the top sub to the mandrel,the coupling comprising 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 comprising 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.2. The tubing swivel of ...

CURVED LINKS FOR WIRING CONDUIT

A downhole tool is disclosed. The downhole tool may include an actuator having a housing, a shaft extending through at least a portion of the housing, and a nut movably disposed on the shaft. Further, the downhole tool may include a wiring conduit disposed in a helix shape around the shaft, and extending between the nut and a fixed position relative to the shaft. The wiring conduit may include a plurality of curved links. Each of the plurality of curved links may include a first hinge and a second hinge, the first hinge of a first curved link pivotably coupled to the second hinge of a second curved link. The downhole tool may also include a wire routed through the wiring conduit. 1. A downhole tool , comprising: a housing;', 'a shaft extending through at least a portion of the housing; and', 'a nut movably disposed on the shaft;, 'an actuator comprisinga wiring conduit disposed in a helix shape around the shaft and extending between the nut and a fixed position relative to the shaft, the wiring conduit comprising a plurality of curved links, each of the plurality of curved links including a first hinge and a second hinge, the first hinge of a first curved link pivotably coupled to the second hinge of a second curved link; anda wire routed through the wiring conduit.2. The downhole tool of claim 1 , wherein the first curved link and the second curved link form a continuously curved path.3. The downhole tool of claim 1 , wherein each of the first hinge and the second hinge includes a channel through which the wire is routed.4. The downhole tool of claim 1 , wherein each of the plurality of curved links further comprises a wire guide located at an apex of the curved link claim 1 , the wire guide including a wire-guide channel through which the wire is routed.5. The downhole tool of claim 4 , wherein the distance from an outer tip of the wire guide of the first curved link to an outer tip of the wire guide of the second curved link is approximately equal to an inner ...

ARTICULATED PLUNGER ROD PUMP

A reciprocating rod pump system, comprising an articulating plunger assembly having a plurality of plunger segments, each having a pin end and a box end, and a ball and socket articulating connector formed between the pin end of one plunger segment and the box end of another plunger segment. The articulating connector is formed from a collar rigidly attached to the pin end, which defines a socket, the collar comprising an internal shoulder which abuts an external shoulder on the plunger pin end, such that the uppermost end of the collar does not contact the plunger segment, and a plunger nipple comprising a ball adapted to fit and rotate within the socket, and a shank which rigidly engages the box end thread of a plunger segment. 1. A reciprocating rod pump system , comprising an articulating plunger assembly comprising:(a) at least two plunger segments, each comprising a pin end and a box end, wherein the pin end has an external threaded portion and the box end has an internally threaded portion;(b) a ball and socket articulating connector, formed between the pin end of one plunger segment and the box end of another plunger segment, which articulating connector comprises:i. a collar rigidly attached to the pin end, the collar and pin end together defining a socket, the collar comprising an internal shoulder which abuts an external shoulder on the pin end, such that the uppermost end of the collar does not contact the plunger segment;ii. a plunger nipple comprising a ball and a shank, wherein the ball is adapted to fit and rotate within the socket, and the shank comprises an external thread which rigidly engages the box end thread of a plunger segment.2. The rod pump system of wherein the ball comprises a travel limiting abutment which contacts a lower surface of the pin end at the rotational travel limit of the ball within the socket claim 1 , and the shank and collar are configured so as to not contact each other at the travel limit.3. The rod pump system of ...

Systems And Methods For Releasing A Portion Of A Drill String From A Drilling Cable

A cable release system for permitting detachment of a drilling cable from a drill string. The cable release system has a swivel body, a bearing assembly, one or more locking elements, and a release sleeve assembly. The swivel body is coupled to a drilling cable. The bearing assembly has a receptacle body that receives a portion of the swivel body and defines openings that receive a portion of corresponding locking elements. The bearing assembly has an outer sleeve that circumferentially surrounds the receptacle body and has a variable inner diameter such that axial movement of outer sleeve controls the radial position of the locking elements relative to the swivel body. The release sleeve assembly can be moved in a distal direction to engage the outer sleeve of the bearing assembly to move the outer sleeve to an axial position in which the swivel body and drilling cable are detachable from the remainder of the drill string. 1. A cable release system comprising:a swivel body configured for coupling to a drilling cable and having a distal end portion, the distal end portion having an outer surface and defining at least one groove that is radially recessed relative to the outer surface; a receptacle body having a wall with an outer surface, the wall having a proximal portion that has an inner surface that defines an interior cavity configured to receive at least a portion of the distal end portion of the swivel body; and', 'an outer sleeve having a wall at least partially circumferentially surrounding the wall of the receptacle body, the wall of the outer sleeve having an inner surface that is radially spaced from the outer surface of the wall of the receptacle body;, 'a bearing assembly havinga plurality of locking elements positioned in engagement with the inner surface of the outer sleeve; anda release sleeve assembly that is axially moveable relative to a drilling axis, wherein, upon movement of the release sleeve assembly in a distal direction relative to the ...

MUD MOTOR DRIVE-SHAFT WITH IMPROVED BEARINGS

An improved arrangement for bearings for a drive-shaft for off-set or bent drive subassemblies between a mud-motor and a drill-bit in a bottom-hole assembly for directional drilling is provided by using elliptically shaped rollers housed in mating slots in the end or ends of the drive shaft to roll on their axes which are approximately perpendicular to the radius of the shaft and approximately aligned with the shaft's longitudinal axis, to engage with other mating slots in driven or driving housings attached to respectively the mud motor and to the drill's driven bit. The rollers are designed so that as the shaft pivots around a centroid of its tip end(s) the shape of the bearings' outer surface rotates within the slots with improved loading characteristics, with more bearing-to-slot surface area and less point loading than arrangements in the prior art, such as tapered roller bearings or ball bearings. 1. a bearing assembly for use in the transmission of torque in a bottom-hole assembly of a drilling system to provide a bendable drill-string while continuing to transfer torque past the bend , comprising:a. a drive attachment to either a driven or drive component of a drive system of a bottom-hole assembly,b. a bonnet attached at an outer end to the drive attachment and with an opening at the other end for a drive-shaft to protrude,c. the drive shaft having a ball-end,d. the bonnet when attached to the drive attachment will rotate simultaneously with the drive attachment's rotation, the bonnet being either driving or driven,e. the bonnet having an internal receptacle to receive the ball-end of the drive shaft and to hold the drive shaft from excessive movement toward or away from the drive attachment,f. the drive shaft having shaft receptacles on its outer surface for receiving a first part of mating rollers,g. the bonnet's interior surface having bonnet receptacles for receiving a second part of the mating rollers,h. the shaft receptacles and the bonnet receptacles ...

ELECTRICAL WELLBORE INSTRUMENT SWIVEL CONNECTOR

An electrical instrument swivel connector has a first housing part and a second housing part rotatably connected to each other. The connection enabling transfer of axial loading between the housing parts. A first insulator body is rotatably engaged with a second insulator body and respectively sealingly engageable with an interior surface of the first housing part and the second housing part. Electrical contact pins are formed into the first insulator body and the second insulator body. The electrical contact pins each terminate in a separate electrical contact wherein the first insulator body rotatably engages the second insulator body. A biased electrical contact is disposed between each respective separate electrical contact in the first insulator body and the second insulator body. 1. An electrical instrument swivel connector , comprising:a first housing part and a second housing part rotatably connected to each other, the connection enabling transfer of axial loading between the first housing part and the second housing part;a first insulator body rotatably engaged with a second insulator body, the first and second insulator bodies respectively sealingly engageable with an interior surface of the first housing part and the second housing part;electrical contact pins formed into the first insulator body and the second insulator body, the electrical contact pins each terminating in a separate electrical contact wherein the first insulator body rotatably engages the second insulator body; anda biased electrical contact disposed between each respective separate electrical contact in the first insulator body and the second insulator body.2. The connector of wherein the electrical contacts in the second insulator body comprise contact rings covering substantially an entire circumference of the second insulator body.3. The connector of wherein the biased electrical contacts comprise a resilient claim 1 , electrically conductive material.4. The connector of wherein the ...

MANIFOLD AND SWIVEL CONNECTIONS FOR SERVICING MULTIPLE WELLS AND METHOD OF USING SAME

A system and method is provided for maintaining a live bore throughout a manifold while alternating between fluid flow to a stimulated wellbore and to an inactive or resting wellbore. At least two fluid inlets deliver fluid to the live bore, the fluid inlets straddling the two or more fluid outlets connected to the respective wellbores. One or more or all of the inlets or outlets can have multiple flow-impinging ports for reducing fluid velocity through each port. In another embodiment a method flushing system is provided for freeze protection for piping for a resting wellbore. Further, high fluid flow swivel connections between the manifold and wellheads simplify installation and reduce operational stresses. 1. A system for delivering fluid from a common fluid source to two or more wellheads , comprising:a manifold having a bore;two or more fluid outlets in communication with the bore and forming a live bore at least between the two or more fluid outlets, each fluid outlet being connected to a corresponding wellhead of the two or more wellheads and having a respective outlet valve between the live bore and the corresponding wellhead, the respective outlet valves being operable to deliver fluid to one wellhead at a time; andat least first and second fluid inlets straddling the live bore and connected to the fluid source, whereinwhen one fluid outlet and wellhead is blocked at its respective outlet valve, fluid is delivered to another of the two or more wellheads through the entire live bore supplied from each of the at least first and second fluid inlets.2. The system of claim 1 , wherein the bore is an axial bore and the at least first and second inlets are located adjacent opposing distal ends of the axial bore claim 1 , the live bore being formed between the at least first and second inlets.3. The system of claim 1 , wherein each fluid outlet has two or more outlet ports.4. The system of claim 1 , wherein each fluid inlet has two or more inlet ports.5. The system ...

RISER SYSTEM

A riser system is provided to eliminate the consequences associated with damage to the annular system while also maintaining the availability of critical safety systems. The riser system may comprise a customizable control housing and external seal control subs that facilitate reciprocation and rotation of a drillpipe or workstring while eliminating damage to the upper annular blow out preventer and allowing the upper annular blow out preventer to function as intended. 1. A method for installing a riser system , comprising:installing a riser adapter above an annular blow out preventer in a wellbore operation, the riser adapter having an inner surface that defines an interior space and a stop shoulder, the riser adapter further having a ram that moves between a retracted position and an extended position where the ram is at least partially located in the interior space, wherein the ram defines a hold shoulder;deploying a polished bore receptacle into the riser adapter, wherein a ridge extends from an outer surface of the polished bore receptacle to define a lower shoulder and an upper shoulder;contacting the lower shoulder of the polished bore receptacle against the stop shoulder of the riser adapter, and extending the ram from the retracted position to the extended position such that the hold shoulder is positioned proximate to the upper shoulder to secure the polished bore receptacle to the riser adapter;installing a plurality of seal system subs on a string, wherein a distance between two subs of the plurality of seal system subs is less than a distance between an upper end and a lower end of the polished bore receptacle; andlowering the string through the polished bore receptacle to isolate an annular space in the wellbore operation.2. The method of claim 1 , further comprising:pressing a seal of the annular blow out preventer against the outer surface of the polished bore receptacle.3. The method of claim 1 , further comprising:reciprocating and rotating the ...

DOWNHOLE SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus which can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve of the swivel. 1. A method of performing operations in a well bore , the method comprising the following steps:(a) attaching a swivel to a drill string, the swivel including a mandrel having a longitudinal axis and a sleeve, the sleeve being rotatably connected to the mandrel with the sleeve including at least one catch that restricts the extent of longitudinal movement of the sleeve relative to an annular blow-out preventer;(b) detachably connecting the blowout preventer to the sleeve which detachable connectgion fluidly separating the riser from the wellbore;(c) during a time period while the blowout preventer is detachably connected to the sleeve and where high differential pressure exists above and below the annular seal of the annular blow-out preventer, and which high differential force attempts to push the sleeve vertically out of the closed annular seal, performing operations in the wellbore, wherein the at least one catch in combination with the closed annular seal prevents the sleeve from being pushed vertically out of the closed annular seal.2. The method of claim 1 , wherein during step “d” a fluid is displaced from the wellbore.3. The method of claim 2 , wherein the fluid is drilling fluid.4. The method of claim 1 , ...

ROTATING AND RECIPROCATING SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus wherein a rotating and reciprocating swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections with the mandrel of the swivel being comprised of double box end joints and using double pin end subs to connect a plurality of such mandrel joints together. 111-. (canceled)12. A method of using a reciprocating swivel in a drill or work string , the method comprising the following steps:(a) positioning a rotating and reciprocating tool adjacent an annular blow out preventer, the tool comprising a mandrel and a sleeve, the sleeve being reciprocable relative to the mandrel and the mandrel including at least one joint having double box ends with the joint being severable by a ram blow out preventer, the sleeve having first and second sealing units, the swivel including an interstitial space between the sleeve and the mandrel with the first and second sealing units each sealing the interstitial space;(b) after step “a”, having the annular blow out preventer close on the sleeve; and(c) after step “b”, causing relative longitudinal movement between the sleeve and the mandrel, wherein in step “a” the mandrel includes two double box end joints which are connected by a double pin end sub, and in step “c” when the double pin end sub is at the same longitudinal position as the first sealing unit, the first sealing unit loses its seal of the interstitial space, but the second sealing keeps its seal of the interstitial space.13. The method of claim 12 , wherein after the double pin end sub passes by the first sealing unit claim 12 , the first sealing unit regains its seal of the interstitial space.14. The method of claim 13 , wherein when the double pin end sub is at the same longitudinal position as the second sealing unit claim 13 , the second sealing unit loses its seal of the interstitial space claim 13 , but the first sealing unit keeps its seal of the ...

SYSTEM AND METHOD FOR ROTATING CASING STRING

In one aspect, a system includes a tool, a hanger connected to the tool, and a plurality of tubulars connected to the hanger and adapted to be positioned within a wellbore. The tool, hanger, and tubulars are rotatable in response to at least the application of torsion to the tool, and without transferring torque to the connection between the tool and the hanger. In another aspect, a method includes positioning a tubular string within a wellbore, connecting a hanger to the tubular string, and applying torsion to the tubular string to rotate the tubular string. To apply torsion to rotate, a tool is connected to the hanger, and torsion is applied to the tool without transferring torque to the connection between the tool and the hanger. In another aspect, there is provided an apparatus for rotating a tubular string in a preexisting structure, such as a wellbore. 1. A system , comprising:a tool;a hanger connected to the tool; anda plurality of tubulars connected to the hanger and adapted to be positioned within a wellbore that traverses a subterranean formation, each of the tubulars being connected to at least one other tubular;wherein the tool, the hanger, and the plurality of tubulars are rotatable in response to at least the application of torsion to the tool; andwherein the tool, the hanger, and the plurality of tubulars are rotatable without transferring torque to the connection between the tool and the hanger.2. The system of claim 1 , wherein the hanger is a casing hanger; andwherein the plurality of tubulars is a casing string.3. The system of claim 1 , wherein the tool claim 1 , the hanger claim 1 , and the plurality of tubulars rotate in response to at least:the application of a tensile load across the tool; andthe application of torsion to the tool during the application of the tensile load across the tool.4. The system of claim 1 , wherein any trapped torsion between any of the respective connections between any two of the tubulars in the plurality of ...

Drill String Constant Velocity Connection

A constant velocity connection for use in a drill string can include at least one ball-and-socket joint, and an insert rotationally received in an opening formed laterally through a ball of the joint. A method of constructing a constant velocity connection can include installing an insert in an opening formed in a ball of at least one ball-and-socket joint of the constant velocity connection, and allowing the insert to rotate in the opening about a lateral axis. A drill string can include a drilling motor, a drill bit, and a constant velocity connection connected between the drilling motor and the drill bit, the constant velocity connection including at least one ball-and-socket joint, and an insert rotationally received in an opening formed laterally through a ball of the joint. 1. A constant velocity connection for use in a drill string , the constant velocity connection comprising:at least one ball-and-socket joint; andan insert rotationally received in an opening formed laterally through a ball of the joint.2. The constant velocity connection of claim 1 , wherein the insert rotates about a first axis relative to the ball claim 1 , and wherein a socket of the joint rotates about the first axis relative to the ball.3. The constant velocity connection of claim 2 , wherein the first axis is perpendicular to the opening.4. The constant velocity connection of claim 2 , further comprising a second axis perpendicular to the first axis claim 2 , and wherein the socket also rotates about the second axis relative to the ball.5. The constant velocity connection of claim 1 , wherein the insert is generally disk shaped.6. The constant velocity connection of claim 1 , further comprising a journal which extends through the insert claim 1 , and wherein a socket of the joint rotates about the journal.7. The constant velocity connection of claim 6 , wherein the socket also rotates about an axis perpendicular to the journal.8. The constant velocity connection of claim 1 , wherein ...

SYSTEMS AND METHODS FOR RELEASING A PORTION OF A DRILL STRING FROM A DRILLED CABLE

A cable release system for permitting detachment of a drilling cable from a drill string. The cable release system has a swivel body, a bearing assembly, one or more locking elements, and a release sleeve assembly. The swivel body is coupled to a drilling cable. The bearing assembly has a receptacle body that receives a portion of the swivel body and defines openings that receive a portion of corresponding locking elements. The bearing assembly has an outer sleeve that circumferentially surrounds the receptacle body and has a variable inner diameter such that axial movement of outer sleeve controls the radial position of the locking elements relative to the swivel body. The release sleeve assembly can be moved in a distal direction to engage the outer sleeve of the bearing assembly to move the outer sleeve to an axial position in which the swivel body and drilling cable are detachable from the remainder of the drill string. 1. A cable release system comprising:a swivel body configured for coupling to a drilling cable and having a distal end portion, the distal end portion having an outer surface and defining at least one groove that is radially recessed relative to the outer surface; a receptacle body having a wall with an outer surface, the wall having a proximal portion that has an inner surface that defines an interior cavity configured to receive at least a portion of the distal end portion of the swivel body; and', 'an outer sleeve having a wall at least partially circumferentially surrounding the wall of the receptacle body, the wall of the outer sleeve having an inner surface that is radially spaced from the outer surface of the wall of the receptacle body;, 'a bearing assembly havinga plurality of locking elements positioned in engagement with the inner surface of the outer sleeve; anda release sleeve assembly that is axially moveable relative to a drilling axis, wherein, upon movement of the release sleeve assembly in a distal direction relative to the ...

DRILL PIPE COMPLETION DEVICE

A method of completing a well which has a longitudinal axis along a direction with a horizontal component, the method comprising rotating a first string and moving the first string into the well along the longitudinal axis of the well, providing a swivel joint rotatably connecting the first string to a second string, moving the second string along the longitudinal axis of the well into the well, wherein the second string comprises completion equipment, moving the completion equipment into the well along the longitudinal axis of the well. 1. A method of completing a well which has a longitudinal axis along a direction with a horizontal component , the method comprising:rotating a first string and moving the first string into the well along the longitudinal axis of the well,providing a swivel joint rotatably connecting the first string to a second string,moving the second string along the longitudinal axis of the well into the well, wherein the second string comprises completion equipment,moving the completion equipment into the well along the longitudinal axis of the well.2. The method of claim 1 , wherein the second string is rotationally at rest during said moving the second string.3. The method of claim 1 , further comprising controlling fluid circulation with a ball operated sleeve provided at the swivel joint.4. The method of claim 1 , further comprising locking the swivel joint with a locking means.5. The method of claim 1 , wherein the swivel joint comprises a ball bearing.6. The method of claim 1 , wherein the swivel joint comprises a thrust washer.7. The method of claim 1 , further comprising means for advancing the first string into the well on rotation of the string.8. The method of claim 7 , wherein said means comprises a pusher sub claim 7 , wherein the pusher sub comprises wheels; and wherein the method further comprises bringing the wheels into contact with the formation or the casing.9. The method of claim 8 , wherein the wheels are brought into ...

DOWNHOLE SWIVEL

A downhole tool includes a first sub, a second sub, and a clutch assembly positioned between the first sub and the second sub. The clutch assembly is configured to allow rotation between the first sub and the second sub in a first direction, and to prevent rotation between the first sub and the second sub in a second, opposite direction, when a compression force is applied to the downhole tool, when a tension force is applied to the downhole tool, and when no axial force is applied to the downhole tool. 1. A downhole tool , comprising:a first sub;a second sub; anda clutch assembly positioned between the first sub and the second sub, wherein the clutch assembly is configured to allow rotation between the first sub and the second sub in a first direction, and to prevent rotation between the first sub and the second sub in a second, opposite direction, when a compression force is applied to the downhole tool, when a tension force is applied to the downhole tool, and when no axial force is applied to the downhole tool.2. The downhole tool of claim 1 , further comprising:an outer housing that is coupled to the second sub such that the outer housing is restrained from rotation relative to the second sub; andan inner mandrel disposed within the outer housing and coupled to the first sub such that the inner mandrel is restrained from rotation relative to the first sub, a body coupled to the inner mandrel, wherein one or more tapered pockets are defined in the body; and', 'one or more clutch elements positioned in the one or more tapered pockets, wherein the one or more clutch elements are configured to produce a mechanical interference that resists rotation of the inner mandrel relative to the outer housing in the second direction., 'wherein the clutch assembly comprises3. The downhole tool of claim 2 , wherein the outer housing is integrally-formed with the second sub claim 2 , and wherein the body of the clutch assembly is integrally-formed with the inner mandrel.4. The ...

SUBMERSIBLE PUMP SYSTEMS AND METHODS OF USE

Systems, methods, and tools for economically performing downhole well maintenance, utilizing a flexible reinforced hose and maintenance tools designed to work with the hose. Tools include well perforation cleaning tools using water jets and/or brushes, pad removal tools, sand bailing tools, and fluid level meters. 1. A system for performing downhole well maintenance comprising:a flexible reinforced hose; a pipe portion comprising a length disposed between a sealed cap at a distal end of the pipe and an attachment portion at a proximal end of the pipe, wherein the attachment portion is configured to be in fluid communication with the flexible hose;', 'a plurality of cleaning devices disposed along the length of the pipe., 'a downhole well perforation cleaning tool configured to be attached to, and lowered by, the flexible reinforced hose, said well perforation cleaning tool comprising2. The system of claim 1 , wherein the plurality of cleaning devices comprise water jets claim 1 , and wherein the system further comprises a reservoir disposed between the proximal end of the pipe and the flexible reinforced hose.3. The system of claim 2 , further comprising a plurality of rotator jets disposed along the length of the pipe positioned parallel to a vertical axis of the pipe and a rotary swivel disposed between the tool and the flexible hose.4. The system of claim 3 , further comprising at least one cleaning brush extending outwardly from the length of the pipe.5. The system of claim 1 , wherein the plurality of cleaning devices comprise retractable brushes.6. The system of claim 1 , further comprising a reservoir tool claim 1 , said reservoir tool comprising a length of tube having a cavity disposed between a proximal opening on one end of the tube and a distal opening on the opposite end of the tube claim 1 , wherein the proximal and distal openings are configured to be attached to the flexible hose and other tools of the system.7. The system of claim 6 , further ...

APPARATUS FOR TRANSMITTING TORQUE THROUGH A WORK STRING

An apparatus for transferring rotational torque from a work string to a subsea infrastructure, said apparatus comprising a first connection () for receiving the work string; a second connection () for receiving the subsea infrastructure tooling; a joint seat () located between the first connection () and the second connection (); a joint body () provided on the joint seat (), wherein the joint body () is connected to the second connection () and wherein the joint body () can articulate freely within the joint seat (); and means for transferring rotational torque from the first connection () to the joint body () and subsequently to the second connection (). 2. The kit of claim 19 , wherein the locking mechanism further comprises at least one handle for operating the at least one locking pin.3. The kit of claim 2 , wherein the at least one locking pin and the at least one handle are a Remote Operated Vehicle locking pin and a Remote Operated Vehicle handle.45-. (canceled)6. The kit of claim 19 , wherein at least one of the joint seat and the joint body comprises a machined profile on its outer surface for receiving the at least one locking pin.7. The kit of claim 1 , wherein claim 1 , when in the locked position claim 1 , the sleeve isolates at least one of the second connection and the joint body against an internal diameter of the sleeve claim 1 , such that the joint body does not move freely.810-. (canceled)11. The kit of claim 1 , wherein the means for transferring rotational torque comprises at least one drive pin provided between the joint body and the joint seat.12. The kit of claim 1 , wherein the means for transferring rotational torque comprises at least one spline portion located on the joint body claim 1 , said spline portion being received in a recess provided in the joint seat.13. The kit of claim 1 , wherein the means for transferring rotational torque comprises a torque key provided in a receptacle located in the first connection and in a recessed ...

FRACTURING MANIFOLD SYSTEMS AND METHODS

A fracturing system is provided. In one embodiment, the fracturing system includes a fracturing manifold for routing fracturing fluid to multiple wells. The fracturing manifold can be coupled via fluid conduits to fracturing trees installed at the wells. In some cases, each fracturing tree that is coupled to the fracturing manifold is coupled by at least one rigid fluid conduit. The fracturing manifold can include a trunk line that provides fracturing fluid to multiple outlet branches, which can include valves for controlling flow of fracturing fluid to wells downstream of the valves. Additional systems, devices, and methods are also disclosed. 1. A system comprising:a fracturing manifold;a plurality of fracturing trees; anda plurality of fluid conduits coupled between the fracturing manifold and the plurality of fracturing trees to enable receipt of fracturing fluid by the plurality of fracturing trees from the fracturing manifold, wherein each fracturing tree of the plurality of fracturing trees coupled to the fracturing manifold is coupled to the fracturing manifold by at least one rigid fluid conduit of the plurality of fluid conduits so as to provide one and only one rigid fluid pathway from the fracturing manifold to the fracturing tree, and the one and only one rigid fluid pathway is not coupled to the fracturing manifold to provide the fracturing fluid from the fracturing manifold to any other fracturing tree; and a first pipe that is attached to a first connection block via a first flanged connection; and', 'a second pipe that is in fluid communication with the first pipe and is attached to the first connection block or to a second connection block via a second flanged connection., 'wherein the at least one rigid fluid conduit includes2. The system of claim 1 , wherein the fracturing manifold includes:a shared trunk conduit for routing fracturing fluid to multiple fracturing trees of the plurality of fracturing trees; andoutlet branches for routing ...

FLEXIBLE PIPE JOINT

A flexible pipe joint () includes a body () having a pin-end member () telescopically fitted within a box-end member (), the pin-end member () including an outer connection profile () and the box-end member () including a complementary inner connection profile (), a bearing () including an outer bearing surface (), wherein the bearing () is fitted within the body () such that at least a portion of an inner body surface () interfaces with at least a portion the outer bearing surface (), and wherein the bearing () includes an inner bearing surface (), and an extension pipe () including an outer extension pipe surface (), wherein the extension pipe () is fitted within the bearing () such that at least a portion of the inner bearing surface () interfaces with at least a portion of the outer extension pipe surface (). 1200. A flexible pipe joint () comprising:{'b': 210', '210', '230', '220, 'claim-text': [{'b': 230', '235', '220', '225', '235', '225, 'wherein the pin-end member () includes an outer connection profile () and the box-end member () includes an inner connection profile (), wherein the outer connection profile () is complementary to the inner connection profile (), and'}, {'b': 210', '212, 'wherein the body () includes an inner body surface ();'}], 'a body (), wherein the body () includes a pin-end member () telescopically fitted within a box-end member (),'}{'b': 240', '240', '244', '240', '210', '212', '244', '240', '243, 'a bearing (), wherein the bearing () includes an outer bearing surface (), wherein the bearing () is fitted within the body () such that at least a portion of the inner body surface () interfaces with at least a portion the outer bearing surface (), and wherein the bearing () includes an inner bearing surface (); and'}{'b': 270', '270', '289', '270', '240', '243', '289, 'an extension pipe (), wherein the extension pipe () includes an outer extension pipe surface (), wherein the extension pipe () is fitted within the bearing () such that ...

WIRED SWIVEL IN WELLBORE DRILLING

A swivel includes a male segment, a female segment, and a lock pin. The male segment can mate with the female segment, and the lock pin can pass through the female segment and engage with the male segment to prevent relative axial movement of the male segment and the female segment while allowing relative rotational movement of the male segment and the female segment. The male segment includes a first conductive ring configured to couple to a first wire. The female segment includes a second conductive ring configured to couple to a second wire. Contact between the first and second conductive rings establishes an electrical connection between the first and second wires. 1. A swivel comprising: an outer circumferential surface defining a groove; and', 'a first conductive ring disposed on the outer circumferential surface, the first conductive ring configured to couple to a first wire disposed within the first drill pipe;, 'a male segment configured to couple to a first drill pipe of a drill string configured to form a wellbore in a subterranean formation, the male segment comprising an inner circumferential surface configured to mate with the outer circumferential surface of the male segment; and', 'a second conductive ring disposed on the inner circumferential surface, the second conductive ring configured to couple to a second wire disposed within the second drill pipe, the second conductive ring configured to contact the first conductive ring when the inner circumferential surface of the female segment mates with the outer circumferential surface of the male segment to establish an electrical connection between the first wire and the second wire; and, 'a female segment configured to couple to a second drill pipe of the drill string, the female segment defining a passageway, the female segment comprisinga lock pin configured to pass through the passageway of the female segment and engage with the groove of the male segment to prevent relative axial movement of the ...

DOUBLE SWIVEL APPARATUS AND METHOD

A double swivel for use with a top drive power unit supported for connection with a well string in a well bore to selectively impart longitudinal and/or rotational movement to the well string, a feeder for supplying a pumpable substance such as cement and the like from an external supply source to the interior of the well string in the well bore without first discharging it through the top drive power unit including a mandrel extending through double sleeves which are sealably and rotatably supported thereon for relative rotation between the sleeves and mandrel. The mandrel and sleeves have flow passages for communicating the pumpable substance from an external source to discharge through the sleeve and mandrel and into the interior of the well string below the top drive power unit. The unit can include a packing injection system, clamp, and novel packing configuration. In an alternative embodiment the unit can include a plug or ball insertion tool. 1. A double top drive swivel insertable into a drill or work string comprising:(a) a first mandrel having upper and lower end sections, the upper section being connectable to and rotatable with an upper drill or work string section, the first mandrel including a longitudinal passage;(b) a first sleeve, the first sleeve being rotatably connected to the first mandrel(c) a first seal between upper and lower end portions of the first mandrel and first sleeve, the first seal preventing leakage of fluid between the first mandrel and first sleeve;(d) the first sleeve comprising an inlet port(e) the first mandrel comprising a plurality of longitudinally spaced apart radial ports in fluid communication with both the inlet port of the first sleeve and the longitudinal passage of the first mandrel to supply pressurized fluid from the inlet port of the first sleeve to the longitudinal passage of the first mandrel;(f) a second mandrel having upper and lower end sections, the upper section being fluidly connected to the lower section ...

AUTOMATED LOCKING JOINT IN A WELBORE TOOL STRING

An automated locking joint is provided. The automated locking joint can include a first member, a second member, a joint, a locking structure, and a positioning device. The joint can connect the first member with the second member. The second member can be pivotable about the joint relative to the first member. The locking structure can be positionable between a lock position that prevents pivoting of the second member about the joint and an unlock position that allows pivoting of the second member about the joint. The positioning device can automatically move the locking structure from the lock position to the unlock position or from the unlock position to the lock position. 1. An automated locking joint , comprising:a first member;a second member;a joint that connects the first member with the second member, the second member pivotable about the joint relative to the first member; anda locking structure automatically positionable between a lock position and an unlock position with respect to the joint based, at least in part, on a change in a pressure condition, the lock position preventing pivoting of the second member about the joint and the unlock position allowing pivoting of the second member about the joint.2. The automated locking joint of claim 1 , wherein the first member is connectable with a first portion of a wire line tool string claim 1 , wherein the second member is connectable with a second portion of the wire line tool string claim 1 , and wherein the joint is at least one of a ball and socket joint claim 1 , a knuckle joint claim 1 , or a hinge.3. The automated locking joint of claim 1 , wherein the locking structure includes a sleeve;wherein, in the lock position, the sleeve is positioned about the first member and the second member to prevent the second member from pivoting about the joint; andwherein, in the unlock position, the sleeve is positioned about the first member or about the second member to allow the second member to pivot about the ...

DRILLER RETAINING DEVICE ABLE TO BE POSITIONED WITH WELL HORIZONTALITY AND VERTICALITY

A driller retaining device able to be positioned with well horizontality and verticality includes a hollow outer sleeve having two end, one is a working end and the other being an assembly end; an inner wall of the assembly end being formed with a plurality of axial sliding tracks; an inner hollow cylinder arranged within the sleeve; two ends of the inner hollow cylinder being an machine end and an assembly end; an outer wall of the inner hollow cylinder having at least one sliding block which is arranged corresponding to the axial sliding groove. In in assembly, the inner hollow cylinder is combined to the driller; then the assembly end of the inner hollow cylinder is assembled to the assembly end of the outer sleeve; and at the same time, the sliding block of the inner hollow cylinder is assembled into the axial sliding groove of the outer sleeve. 1. A driller retaining device able to be positioned with well horizontality and verticality; comprising:a hollow outer sleeve having two end, one being a working end and the other being an assembly end; an inner wall of the assembly end being formed with a plurality of axial sliding tracks;an inner hollow cylinder arranged within the sleeve; two ends of the inner hollow cylinder being an machine end and an assembly end; an outer wall of the inner hollow cylinder having at least one sliding block which is arranged corresponding to the axial sliding groove of the outer sleeve;wherein in assembly, the inner hollow cylinder is combined to the driller; then the assembly end of the inner hollow cylinder is assembled to the assembly end of the outer sleeve; and at the same time, the sliding block of the inner hollow cylinder is assembled into the axial sliding groove of the outer sleeve.2. The driller retaining device able to be positioned with well horizontality and verticality as claimed in claim 1 , wherein the inner hollow cylinder has a retaining unit for retaining a driller inserting to an inner space of the inner hollow ...

Rotating and reciprocating swivel apparatus and method

What is provided is a method and apparatus wherein a swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve or housing can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve or housing of the swivel.

SPOOLABLE SWIVEL

A spoolable swivel, methods, and systems for coupling a first and second length of coiled tubing. The spoolable swivel can include an inner tubular element and an outer tubular element. The inner tubular element and the outer tubular element can both have dimpled distal ends and races on their proximal ends, defining one or more annular voids for swivel bearings. 1. A spoolable swivel for coupling a first and second length of coiled tubing comprising: a first distal end having a first distal surface,', 'a first proximal end having a first proximal surface, and', 'a first race disposed on the first proximal surface; and, 'an inner tubular element having'} a second proximal end having a second proximal surface,', 'a second race disposed on the second proximal surface, and', 'a second distal end having a second distal surface,, 'an outer tubular element having'}wherein the first race aligns with the second race to define an annular void when the first proximal end of the inner tubular element is inserted into the second proximal end of the outer tubular element, andwherein a plurality of bearings are positioned within the annular void to provide a swiveling coupling between the inner tubular element and the outer tubular element.2. The spoolable swivel according to claim 1 , further comprising:a first plurality of dimples disposed on the first distal surface, anda second plurality of dimples disposed on the second distal surface.3. The spoolable swivel according to claim 2 , wherein the first length of coiled tubing is attached to the inner tubular element via the first plurality of dimples claim 2 , and wherein the second length of coiled tubing is attached to the outer tubular element via the second plurality of dimples.4. The spoolable swivel according to claim 1 , further comprising at least one additional annular void defined by one or more additional races disposed on the first proximal and on the second proximal surface claim 1 ,wherein at least one additional ...

COILED TUBING SWIVEL ASSEMBLY

An oilfield assembly including a pump in fluid communication with a string of coiled tubing on a tubing reel through a coiled tubing swivel assembly, includes a fluid inlet segment coupled to a swivel body having a central axis, and a rotatable hollow shaft having a portion that extends axially within the swivel body, wherein the fluid inlet segment, swivel body and hollow rotatable shaft form a conduit for passage of a pumped substance to the tubing reel from the pump. The rotatable shaft includes a first end attachable to the tubing reel, and a distal second end, at least part of which is configured to engage a corresponding indentation in the body, thereby preventing direct contact between the distal end of the shaft and the pumped substance. 1. An oilfield assembly comprising a pump in fluid communication with a string of coiled tubing on a tubing reel through a coiled tubing swivel assembly , the coiled tubing swivel assembly comprising:a fluid inlet segment coupled to a swivel body having a central axis; anda rotatable hollow shaft having a portion that extends axially within the swivel body, wherein the fluid inlet segment, swivel body and rotatable hollow shaft form a conduit for passage of a pumped substance to the tubing reel from the pump,the rotatable hollow shaft comprising a first end attachable to the tubing reel, and a distal second end, at least part of which is configured to engage a corresponding indentation in the swivel body.2. The swivel assembly of claim 1 , further comprising one or more rotary seals arranged circumferentially around an outer surface of the shaft and proximate to the distal second end of the shaft.3. The swivel assembly of claim 1 , further comprising one or more bearing assemblies disposed radially between the rotatable shaft and the swivel body claim 1 , each bearing assembly comprising:a plurality of rolling elements radially disposed between (i) an outer race configured for a clearance fit with an inner surface of the ...

ROTATING AND RECIPROCATING SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus wherein a swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve or housing can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve or housing of the swivel. 130-. (canceled)31. A method of using a reciprocating swivel in a drill or work string , the method comprising the following steps:(a) lowering a rotating and reciprocating swivel tool to a BOP, the swivel tool comprising a mandrel and a sleeve, the sleeve being reciprocable relative to the mandrel and the swivel tool including a quick lock/quick unlock system which has locked and unlocked states, the swivel tool including an interstitial space between the sleeve and the mandrel, the interstitial space having an interstitial pressure relief mode and an interstitial non-pressure relief mode, the swivel tool being reversibly switchable between pressure relief and non-pressure relief modes;(b) after step “a”, having the BOP close on the sleeve;(c) causing relative longitudinal movement between the sleeve and the mandrel and activating the quick lock/quick unlock system to cause the quick lock/quick unlock to change from an unlocked to a locked state.32. The method of claim 31 , wherein in step “a” claim 31 , the sleeve is longitudinally locked relative to the mandrel.33. The method of claim 31 , wherein claim 31 , after step “b” and before step “c” claim 31 , the sleeve is unlocked ...

DIRECT PULLBACK DEVICES AND METHOD OF HORIZONTAL DRILLING

An apparatus for horizontal directional drilling includes a housing and a sonde transmitter mounted in the housing. The housing includes a main fluid channel to permit a flow of a fluid therethrough. The apparatus further includes a fluid outlet at the front of the housing in communication with the main fluid channel and adapted to emit fluid from the front of the housing during pilot bore operations. The housing further includes a plurality of fluid ports in fluid communication with the main fluid channel and adapted to emit fluid from the housing during pullback operations. Drill bits, drill bit adapters, swivel connectors, and tow heads adapted to be coupled to the drill bits for direct pullback operations, as well as methods of direct pullback operations during horizontal direction drilling are also provided. 1. A cutting block for attachment to a horizontal drilling apparatus , the cutting block comprising:a body including at least one cutting element extending therefrom, the at least one cutting element being adapted to cut through soil; andfirst and second arms extending from the body, the first and second arms having an opening therebetween configured to permit a portion of the horizontal drilling apparatus to pass therethrough, the first and second arms including opposed portions adapted to permit the first and second arms of the cutting block to slide over corresponding portions of the horizontal drilling apparatus such that the portion of the horizontal drilling apparatus passes through the opening between the first and second arms of the cutting block and the first and second arms of the cutting block at least in part surround the portion of the horizontal drilling apparatus; andat least one of the first and second arms including at least one fastener-receiving hole passing therethrough and adapted to permit a fastener to pass therethrough to attach the at least one of the first and second arms of the cutting block to the horizontal drilling apparatus.2. ...

Rotary locking sub for angular alignment of downhole sensors with high side in directional drilling

Adjustment of the angle of a bent sub or other steering feature in a drill string relative to a reference angle of a downhole sensor is facilitated by a rotatable coupling between the bent sub and the sensor. The rotatable coupling may be rotated to align the high side with a reference indicium and locked at the set angle. Rows of ceramic balls retained in circumferential channels may be provided to permit rotation while carrying tensile and compressional forces. Calibration of the sensor is facilitated and opportunities for certain measurement errors are eliminated. An embodiment provides a mechanism for locking the rotatable coupling at a desired angle. The embodiment comprises a ring with teeth that engage a downhole portion of the coupling and depressions that engage an uphole portion of the coupling.

Linear Brushless Contact Slip For High Pressure and High Temperature Downhole Application

A linear electrical contact slip structure for conducting electricity between two regions of a tool string while deployed within a wellbore. The linear electrical contact slip maintains an electrical connection between a piston structure and a collar structure, where either structure can be a stroker section or a stator section, and where the electrical connection is maintained when the stoker section is either stationary or in motion. The electrical connections between the piston and collar are grouped along the interior hollow surface of the collar, corresponding to contacts on the exterior of the piston head. The piston and collar are configured to prevent relative rotational motion, but to allow relative linear motion, by use of projections from the piston that match grooves in the collar. 1. A linear electrical contact slip structure of a tool string , comprising:a piston structure, coupled to an uphole tool string section having uphole electrical leads, the piston structure providing one or more piston electrical contact regions that are electrically coupled to the uphole electrical leads; anda collar structure, coupled to a downhole tool string section having downhole electrical leads, the collar structure providing one or more collar electrical contact regions that are electrically coupled to the downhole electrical leads, where the one or more piston electrical contact regions and the one or more collar electrical contact regions arranged to maintain electrical communication where either of the piston structure or the collar structure are stationary or in motion.2. The linear electrical contact slip according to claim 1 , wherein the piston structure is a stroker section and the collar structure is a stator section.3. The linear electrical contact slip according to claim 1 , wherein the collar structure is a stroker section and the piston structure is a stator section.4. The linear electrical contact slip according to claim 1 , wherein the piston structure ...

Apparatus for angular alignment of downhole sensors with high side in directional drilling

Adjustment of the angle of a bent sub or other steering feature in a drill string relative to a reference angle of a downhole sensor is facilitated by a rotatable coupling between the bend sub and the sensor. The rotatable coupling may be rotated to align the high side with a reference indicia and locked at the set angle. Calibration of the sensor is facilitated and opportunities for certain measurement errors are eliminated. An embodiment provides a locking mechanism comprising tapered locking fingers which are clamped against a surface by a tapered collar. Rows of ceramic balls retained in circumferential channels may be provided to permit rotation while carrying tensile and compressional forces.

Drill String Apparatus with Integrated Annular Barrier and Port Collar, Methods, and Systems

A drill string apparatus includes an upper casing section having a port collar. The port collar provides a controllable opening from an interior of the upper casing section to an annulus around the upper casing section. A lower casing section is coupled to the upper casing section through a swivel. The lower casing section includes an external casing packer and a casing pad coupled to an external portion of the lower casing section. The external casing packer is expandable to an annulus around the lower casing section before a cement operation to avoid cement loss circulation to weak formation below the packer. Methods and systems are also disclosed. 1. A directional drill string apparatus , comprising:an upper casing section comprising a port collar that provides an opening from the upper casing section to an annulus around the upper casing section; and an annular barrier coupled to an external portion of the lower casing section; and', 'a casing pad coupled to an external portion of the lower casing section;, 'a lower casing section coupled to the upper casing section through a swivel, the lower casing section comprisingwherein the external casing packer is expandable to an annulus around the lower casing section prior to cementing.2. The drill string apparatus of claim 1 , further comprising a rotary steerable system (RSS) and RSS housing disposed within the lower casing section.3. The drill string apparatus of claim 2 , wherein the RSS housing is coupled to the lower casing with at least one set of latches such that the RSS housing is substantially rotationally stationary with respect to the upper casing section.4. The drill string apparatus of claim 3 , wherein the lower casing section is configured to be stationary while the upper casing section is configured to rotate with the port collar open during the cementing.5. The drill string apparatus of claim 4 , further comprising a drill bit coupled to an internal shaft of the RSS.6. The drill string apparatus of ...

CV JOINT FOR DRILLING MOTOR AND METHOD

A CV joint for a downhole drilling motor includes a center shaft including a top shaft section and a bottom shaft section. The top shaft section is at least partially housed within a cavity of a first insert, which is housed within a cavity of a rotor adapter. The bottom shaft section is at least partially housed within a cavity of a second insert, which is housed within a cavity of a drive shaft adapter. An outer surface of the top and bottom shaft sections may include multiple top shaft pockets and multiple bottom shaft pockets, respectively. The first and second inserts may each include a series of recesses. Top shear members may be partially housed within the top shaft pockets and the recesses of the first insert. Bottom shear members may be partially housed within the bottom shaft pockets and the recesses of the second insert. 1. A CV joint for a downhole drilling motor , comprising:a center shaft including a top shaft section and a bottom shaft section;a first insert including a cavity housing the top shaft section;a second insert including a cavity housing the bottom shaft section;a rotor adapter including a cavity housing the first insert; anda drive shaft adapter including a cavity housing the second insert.2. The CV joint of claim 1 , wherein the first and second inserts each comprises a wear resistant material.3. The CV joint of claim 2 , wherein the wear resistant material is a ceramic material claim 2 , tungsten carbide claim 2 , chromium carbide claim 2 , titanium carbide claim 2 , or tool steel.4. The CV joint of claim 1 , wherein the first and second inserts each comprise a wear resistant surface.5. The CV joint of claim 1 , wherein a material of the first and second inserts has a hardness value that is greater than a hardness value of a material of the rotor adapter and the drive shaft adapter.6. The CV joint of claim 5 , wherein the material of the first and second inserts has a Brinell hardness value of 500 BHN or greater.7. The CV joint of claim ...

LOCKABLE SWIVEL APPARATUS

A swivel apparatus includes upper and lower housings having a passage therethrough operably connected with a coupling for selective relative rotation; at least one movable piston having a first position where the housings are rotationally locked to each other and a second position where the housings are free for relative rotation; the piston is retained to the upper housing with a retainer secured within and discrete from the upper housing, and the retainer is axially spaced from a bearing assembly. 1. A swivel apparatus , comprising:upper and lower housings having a passage therethrough operably connected with a coupling for selective relative rotation;at least one movable piston having a first position where said housings are rotationally locked to each other and a second position where said housings are free for relative rotation;wherein said piston is retained to said upper housing with a retainer secured within and discrete from said upper housing, said retainer axially spaced from a bearing assembly.2. The assembly of claim 1 , wherein said retainer radially disposed between said piston and said upper housing when said piston is in said second position.3. The assembly of claim 1 , wherein said bearing assembly compnses a thrust bearing.4. The assembly of claim 1 , wherein said upper housing is a single component.5. The assembly of claim 1 , wherein said bearing assembly comprises radial bearings on opposed sides of a thrust bearing.6. The assembly of claim 1 , wherein said bearing assembly compnses a larger diameter thrust bearing than a pair of adjacent radial bearings.7. The assembly of claim 1 , wherein said bearing assembly comprises rolling element bearings.8. The assembly of claim 1 , wherein said upper and lower housings comprise splines and said piston comprises spaced splines that selectively engage both splines on said upper and lower bodies for selective rotational locking of said bodies claim 1 , and said splines are axially spaced from said ...

ROTATING AND RECIPROCATING SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus wherein a swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve or housing can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve or housing of the swivel. 162-. (canceled)63. A method of using a reciprocating swivel in a drill or work string , the method comprising the following steps:(a) lowering a rotating and reciprocating tool to a BOP, the tool comprising a mandrel and a sleeve, the sleeve being reciprocable relative to the mandrel and the swivel including a quick lock/quick unlock system which has locked and unlocked states;(b) after step “a”, having the BOP close on the sleeve;(c) after step “b”, causing relative longitudinal movement between the sleeve and the mandrel and causing the quick lock/quick unlock system to enter an unlocked state; (d) after step “c”, moving the sleeve outside of the BOP;(e) after step “d”, moving the sleeve inside of the BOP and having the BOP close on the sleeve; and(f) after step “e”, causing relative longitudinal movement between the sleeve and the mandrel and activating the quick lock/quick unlock system.64. The method of claim 63 , wherein in step “a” claim 63 , the sleeve is longitudinally locked relative to the mandrel.65. The method of claim 63 , wherein claim 63 , after step “b” claim 63 , the sleeve is unlocked longitudinally relative to the mandrel.66. The method of claim 63 , wherein ...

CONSTANT VELOCITY JOINT APPARATUS, SYSTEMS, AND METHODS

The disclosure describes a constant velocity joint assembly for use in transmitting torque. The constant velocity joint assembly includes members that are connected in series via tongue-and-groove connections in a swivel joint pattern that allows for transferring torque between two skew lines, and further provide freedom of movement such that rotation about one longitudinal axis can be transformed into rotation about another longitudinal axis that is not aligned with the first longitudinal axis. Thus, the members of the constant velocity joint assembly do not necessarily need to share a common longitudinal axis. 1. An apparatus , comprising:a first member having a groove in a first end of the first member and a hole penetrated by a longitudinal axis of the first member;a second member having a tongue in a first end of the second member and a hole penetrated by a longitudinal axis of the second member;two intermediary members positioned between the first and second members, each intermediary member having a groove in a first end and a tongue in a second end of the intermediary members, wherein each intermediary member includes a hole penetrated by a longitudinal axis of each intermediary member, and wherein the groove in the first end and the tongue in the second end of each intermediary member are oriented out of alignment with each other; anda coupling element to mechanically couple the first and the second members, wherein the coupling element traverses the holes penetrated by the longitudinal axes of the first member, the second member, and the intermediary members.2. The apparatus of claim 1 , further comprising:a third intermediary member positioned between the first and second members, the third intermediary member having a groove in a first end and a tongue in a second end, wherein the third intermediary member includes a hole penetrated by a longitudinal axis of the third intermediary member, and wherein the groove in the first end and the tongue in the ...

DOWNHOLE SWIVEL SUB

The invention relates to a swivel sub for a string to be lowered into a wellbore and a method of operation in a wellbore, wherein such swivel sub is used and comprises: a first end provided with connection means for connecting a bottom section of a string; a second end provided with connection means for connecting an upper section of the string; a first member, including the first end and a sleeve portion opposed to the first end; a second member including the second end and comprising a section op posed to the second end and partially located within the sleeve portion; the first member and the second member being arranged to rotate relative to each other. 1100100. Method of operation in a wellbore , including a step of deploying a string within said wellbore , wherein a swivel sub () is provided , said swivel sub () comprising:{'b': '114', 'a first end () provided with connection means for connecting a bottom section of a string;'}{'b': '115', 'a second end () provided with connection means for connecting an upper section of the string;'}{'b': 101', '114', '101', '114, 'a first member (), including said first end () and a sleeve portion (′) opposed to said first end ();'}{'b': 102', '115', '102', '115', '101, 'a second member () including said second end () and comprising a section (′) opposed to said second end () and partially located within the sleeve portion (′);'}{'b': 101', '102', '114', '100', '115', '100, 'the first member () and the second member () being arranged to rotate relative to each other, and wherein the first end () of said swivel sub () is connected to a bottom section of the string, the second end () of said swivel sub () is connected to an upper section of the string, and the upper section of the string is rotated in a first direction during deployment of said string in the wellbore while said bottom section is not rotating.'}2100. Method of operation in a wellbore according to claim 1 , wherein said string is a casing string and wherein the ...

SWIVEL

A swivel configured to rotationally decouple an upper section of a work string from a lower section of the work string. The swivel includes an upper body coupled to a lower body by a ring member and a plurality of shearable members. The lower body has a plurality of teeth members that engage a plurality of teeth members of the ring member. Rotation of the upper body is transmitted to the lower body by the ring member. The upper body is rotatable relative to the lower body when the shearable members are sheared.

ROTATING AND RECIPROCATING SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus wherein a swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve or housing can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve or housing of the swivel. 1. A marine oil and gas well drilling apparatus comprising:(a) a marine drilling platform;(b) a drill string that extends between the marine drilling platform and a formation to be drilled, the drill string having a flow bore;(c) a mandrel having upper and lower end sections and connected to and rotatable with upper and lower sections of the drill string, the mandrel having an external diameter and including a longitudinal passage forming a continuation of a flow bore of the drill string sections;(d) a sleeve having a longitudinal sleeve passage and an internal diameter, the sleeve being rotatably connected to the mandrel;(e) an interstitial space between the internal diameter of the sleeve and the external diameter of the mandrel;(f) a pressure relief mechanism that gradually relieves the interstitial space when the mandrel and sleeve are elevated in a well bore.2. The marine oil and gas well drilling apparatus of claim 1 , wherein the pressure relief mechanism includes a pair of spaced apart packing units.3. The marine oil and gas well drilling apparatus of claim 1 , wherein the packing units are placed in opposing sealing directions.4. The marine oil and gas well drilling ...

ROTATING AND RECIPROCATING SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus wherein a rotating and reciprocating swivel can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections with the mandrel of the swivel being comprised of double box end joints and using double pin end subs to connect a plurality of such mandrel joints together. 111-. (canceled)12. A method of using a reciprocating swivel in a drill or work string , the method comprising the following steps:(a) positioning a rotating and reciprocating tool adjacent an annular blow out preventer, the tool comprising a mandrel and a sleeve, the sleeve being reciprocable relative to the mandrel and the mandrel including at least one joint having double box ends with the joint being severable by a ram blow out preventer, the sleeve having first and second sealing units, the swivel including an interstitial space between the sleeve and the mandrel with the first and second sealing units each sealing the interstitial space;(b) after step “a”, having the annular blow out preventer close on the sleeve; and(c) after step “b”, causing relative longitudinal movement between the sleeve and the mandrel, wherein in step “a” the mandrel includes two double box end joints which are connected by a double pin end sub, and in step “c” when the double pin end sub is at the same longitudinal position as the first sealing unit, the first sealing unit loses its seal of the interstitial space, but the second sealing keeps its seal of the interstitial space.13. The method of claim 12 , wherein after the double pin end sub passes by the first sealing unit claim 12 , the first sealing unit regains its seal of the interstitial space.14. The method of claim 13 , wherein when the double pin end sub is at the same longitudinal position as the second sealing unit claim 13 , the second sealing unit loses its seal of the interstitial space claim 13 , but the first sealing unit keeps its seal of the ...

STREAMLINED TRANSMISSION ASSEMBLY

A Streamlined Transmission assembly is used to convert eccentric rotation created by the power section into concentric rotation to be received by a bearing assembly in order to drive the rotation of a drill bit attached to a drilling assembly section of a downhole tool. The Streamlined Transmission assembly can be configured with a joint that can alter the angle of the bottom hole assembly by the use of a bent housing section while maintaining the capability to transfer large torque loads. The joint of the bent housing section of the assembly is configured to decrease deterioration of a lower seal boot and wash in the lower joint by reducing the volume of turbulent flow adjacent to each structure. 1. A downhole power section transmission comprising:a rotor, a CV shaft, and a drive coupling, configured such that the rotor transmits torque to the CV shaft, the CV shaft transmits torque to the drive coupling, and the drive coupling transmits torque to other downhole components to drive rotation of a drill bit;the rotor further comprising a rotor adaptor configured with a first drill bit facing cup section,the CV shaft connected to the rotor adaptor at the first drill bit facing cup section through a first rotating joint;the CV shaft further comprising a second drill bit facing cup section,the drive coupling connected to the CV shaft at the second drill bit facing cup section through a second rotating joint; andthe drive coupling configured to couple with a thrust receiving section of a downhole drill bit assembly.2. The downhole power section transmission of wherein the first rotating joint comprises a ball bearing style rotating joint.3. The downhole power section transmission of wherein the second rotating joint comprises a ball bearing style rotating joint.4. The downhole power section transmission of wherein the first rotating joint comprises a torque dowel style rotating joint.5. The downhole power section transmission of wherein the second rotating joint ...

Universal Joint

A universal joint assembled in a drill string transfers torque between two components where rotation of the components may not be completely aligned. The universal joint includes upper and lower members with radial teeth connected by a serpentine retainer. As the joint rotates the members can pivot within the confines of the serpentine retainer to accommodate misalignment of the components. Axial force can be transferred through a bearing member between the members. 1. A universal joint assembly to be used as part of a downhole drill string , comprising:an upper member and a lower member, each with a longitudinal axis of rotation;a first plurality of engaging elements disposed around a perimeter of the upper member;a second plurality of engaging elements around a perimeter of the lower member; anda flexible retainer coupled with the first and second plurality of engaging elements for transmitting torque between the upper and lower members.2. The universal joint of claim 1 , wherein each of the first and the second plurality of engaging elements are each comprised of teeth disposed around the perimeters of the member claim 1 , separated by slots claim 1 , for engaging the retainer.3. The universal joint of claim 1 , wherein the first and the second plurality of engaging elements are comprised of pins.4. The universal joint of claim 1 , wherein the retainer comprises a serpentine retainer that allows for limited claim 1 , relative movement between the upper and lower members to accommodate axial claim 1 , angular and lateral misalignment the respective longitudinal axes of rotation of the upper and lower members.5. The universal joint of claim 4 , wherein the serpentine retainer allows for limited rotation of the upper member in relation to the lower member.6. The universal joint of claim 4 , wherein the serpentine retainer is elastic.7. The universal joint of wherein each of the engaging elements in the first and second plurality of engagements elements extend in a ...

DOWNHOLE SWIVEL APPARATUS AND METHOD

What is provided is a method and apparatus which can be detachably connected to an annular blowout preventer thereby separating the drilling fluid or mud into upper and lower sections and allowing the fluid to be displaced in two stages, such as while the drill string is being rotated and/or reciprocated. In one embodiment the sleeve can be rotatably and sealably connected to a mandrel. The swivel can be incorporated into a drill or well string and enabling string sections both above and below the sleeve to be rotated in relation to the sleeve. In one embodiment the drill or well string does not move in a longitudinal direction relative to the swivel. In one embodiment, the drill or well string does move longitudinally relative to the sleeve of the swivel. 118-. (canceled)19. A method of performing operations in a wellbore , the method comprising the following steps:(a) attaching a swivel to a drill string, the swivel including a mandrel having a longitudinal axis and a sleeve, the sleeve being rotatably connected to the mandrel with the sleeve including at least one catch that restricts the extent of longitudinal movement of the sleeve relative to a blow-out preventer, the blowout preventer being fluidly connected to a wellbore and a riser;(b) detachably connecting the blowout preventer to the sleeve by closing a seal of the blowout preventer which detachable connection fluidly separating the riser from the wellbore;(c) during a time period while the blowout preventer is detachably connected to the sleeve and where high differential pressure exists above and below the seal of the blow-out preventer, and which high differential force attempts to push the sleeve vertically out of the closed seal, performing operations in the wellbore, wherein the at least one catch in combination with the closed seal prevents the sleeve from being pushed vertically out of the closed seal.20. The method of claim 19 , wherein during step “c” a fluid is displaced from the wellbore.21. ...