An apparatus for supporting an oilfield tubular includes a body defining a tapered bowl and a pocket formed in the body, a cage extending axially through the body, wherein guides are attached to the cage, a slips assembly including slips configured to engage a tubular received in the body. The slips extend radially through the cage and engage the guides, and are movable between a retracted configuration in which the slips are received at least partially within the pocket and an extended position in which the slips slide against the tapered bowl. The apparatus also includes a lifting assembly coupled to the slips and configured to apply a linear, axially-directed force to the slips. The slips are guided to move radially and axially in response to the linear, axially-directed force by the guides.
A downhole tool includes an inner mandrel including external threads. The downhole tool also includes a lock ring positioned around the inner mandrel. The lock ring includes a plurality of segments that are circumferentially-offset from one another. Each segment includes an inner lock segment portion including internal threads that are configured to engage the external threads of the inner mandrel. Each segment also includes an outer lock segment portion that is positioned radially-outward from the inner lock segment portion. Each segment also includes a plurality of shear elements extending at least partially radially-through the inner lock segment portion and the outer lock segment portion to couple the inner lock segment portion and the outer lock segment portion together. The shear elements are configured to shear in response to a predetermined force to decouple the inner lock segment portion from the outer lock segment portion.
Apparatus and methods for extending rig bails, of which the method includes bringing a rig bail towards a connector end of a quick bail system such that an eyelet of the rig bail makes contact with a latch pin of the quick bail system so that the latch pin is moved to an open position, moving the eyelet of the rig bail to enter the connector end of the quick bail system and aligning the rig bail with the quick bail system, lowering the rig bails until the eyelet of the rig bail is fully entered into the connector end of the quick bail system, and returning the latch pin to a closed position.
A clamp installation system includes a clamp head configured to engage a top section and a bottom section of an axially-retained control line clamp. The clamp installation system also includes a manipulator assembly configured to bring the clamp head close to and away from a tubular string run into a well. The clamp head is configured to position the top and bottom sections of the axially-retained control line clamp on opposite axial sides of a coupling of the tubular string. The clamp head is configured to drive the top and bottom sections of the axially-retained control line clamp axially-together so as to secure the axially-retained control line clamp to the coupling.
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
An installation system for installing a control line clamp onto a tubular string includes a first load plate, a second load plate that is offset from the first load plate, the first and second load plates being configured to engage a first clamp member and a second clamp member, respectively, positioned on a tubular string, a retention lid positioner configured to couple the retention lid with the first and second clamp members, a sensor system configured to provide feedback signals representing that the first and second load plates are received around the tubular and aligned with a control line, the retention lid is positioned at a target location and aligned with the control line, and the first and second load plates are adducted together to press the first and second clamp members together, and an indication device configured to indicate a state of the installation system.
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
A cementing system includes an inner string configured to be received into a casing string in a wellbore. The cementing system also includes a stinger coupled to the inner string and configured to be received into a float shoe connected to the casing string. The cementing system also includes a first retractable joint coupled to the inner string. The retractable joint is configured to reduce in axial length so as to permit at least part of stinger to be withdrawn from engagement with the float shoe while a weight of the inner string is supported by a hanger running tool and casing hanger connected to the casing. The inner string, the stinger, and the retractable joint form at least a part of a flowpath that extends through an end of the casing string at the float shoe.
A portable catwalk sensing device includes a proximity detector configured to detect a proximity of a conveyor portion of a catwalk tubular transport machine, a tubular carried by the catwalk tubular transport machine, or both, to a predetermined location relative to the rig floor. The device also includes a module having a processor, and configured to communicate with the proximity detector and receive data representing proximity of the catwalk tubular transport machine, the tubular, or both from the proximity detector, a rig floor, or a combination thereof. The module includes a housing and is configured to be portable. The device also includes an alarm coupled to or integral with the module. The alarm is configured to communicate with the processor, such that the processor is configured to cause the alarm to provide an indication to a user of the proximity of the catwalk tubular transport machine, the tubular, or both.
An apparatus includes a key disposed at least partially in a first recess in a first tubular, the key defining teeth facing in a first axial direction, a first biasing member biasing the key in the first axial direction relative to the first tubular, and a rack disposed at least partially in a second recess formed in a second tubular. The rack defines teeth that face in a second axial direction that is opposite to the first axial direction, the teeth of the rack being configured to mesh with the teeth of the key. The apparatus also includes a second biasing member engaging the rack and biasing the rack in a first circumferential direction, the rack being configured to reciprocate circumferentially relative to the second tubular by engagement with the key and the second biasing member, in response to the first tubular being rotated into connection with the second tubular.
An apparatus includes a key disposed at least partially in a first recess in a first tubular, the key defining teeth facing in a first axial direction, a first biasing member biasing the key in the first axial direction relative to the first tubular, and a rack disposed at least partially in a second recess formed in a second tubular. The rack defines teeth that face in a second axial direction that is opposite to the first axial direction, the teeth of the rack being configured to mesh with the teeth of the key. The apparatus also includes a second biasing member engaging the rack and biasing the rack in a first circumferential direction, the rack being configured to reciprocate circumferentially relative to the second tubular by engagement with the key and the second biasing member, in response to the first tubular being rotated into connection with the second tubular.
An anchor-packer assembly includes a packer having a slips assembly and a seal. The slips assembly and the seal are radially expandable so as to engage a surrounding tubular. The assembly also includes an anchor coupled to the packer. The anchor includes a slips assembly and is configured to transmit a first torque and a first axial force to the packer, to set the packer. The anchor is configured to be actuated from an anchor running position in which the slips assembly thereof is retracted, to an anchor set position, in which the slips assembly thereof is expanded radially outward, in response to a second torque and a second axial force, and the anchor in the anchor set position is configured to prevent an uphole-directed force on the packer from releasing the slips assembly of the packer from engagement with the surrounding tubular.
A system for laying pipe includes a conveyor configured to receive one or more pipes, and one or more friction stir welding (FSW) machines configured to connect the one or more pipes to a pipeline deployed toward a sea floor.
B23K 20/00 - Non-electric welding by applying impact or other pressure, with or without the application of heat, e.g. cladding or plating
B23K 20/12 - Non-electric welding by applying impact or other pressure, with or without the application of heat, e.g. cladding or plating the heat being generated by frictionFriction welding
An apparatus for reducing torque in a drill string includes a clamp assembly having a first clamp segment and a second clamp segment, the first and second clamp segments each being generally arcuate and configured to connect together so as to secure the clamp assembly around an oilfield tubular and prevent the clamp assembly from axial and rotational movement relative to the oilfield tubular. The first and second clamp segments each include a first extension and a second extension, each of the first and second extensions having a tapered end that decreases in outer diameter as proceeding in an axial direction, so as to provide a conical guide surface. An outer sleeve is positioned around the clamp assembly, is configured to rotate with respect to the oilfield tubular and the clamp assembly, and is prevented from axial movement relative thereto.
09 - Scientific and electric apparatus and instruments
Goods & Services
(1) Consolidated electronic control systems for machines, namely, oil rig equipment; Consolidated electrical integrated control systems for use in the field of oil rig equipment.
Oil field equipment, namely, drilling rig mechanization machines and devices using artificial intelligence for optimizing tubular make-ups for use in facilitating step changes in drilling rigs
09 - Scientific and electric apparatus and instruments
Goods & Services
Consolidated electronic control systems for machines, namely, oil rig equipment; Consolidated electrical integrated control systems for use in the field of oil rig equipment
A ruggedized bidirectional cutting system with an outer wear band having a first blade-free fitting section engaging within the drill string and a first cutting section integral with the first blade-free fitting section. The first cutting section has a plurality of blades, each blade with two cutting portions extending at defined cutting angles and a blade cutting portion extending at a third angle from the longitudinal axis different from the first and second angles. Each blade has cutting inserts. A plurality of flutes are formed between pairs of blades to stabilizes and protects bottom hole equipment while a wellbore completes directional drilling objectives.
An apparatus for reducing torque in a drill string includes a clamp assembly having a first clamp segment and a second clamp segment, the first and second clamp segments each including two circumferential ends, the two circumferential ends of the first clamp segment being configured to be connected to the two circumferential ends of the second clamp segment so as to secure the clamp assembly around an oilfield tubular and prevent the clamp assembly from rotating relative to the oilfield tubular. An outer diameter surface of each of the first and second clamp segments is generally continuous in an axial direction. The apparatus also includes an outer sleeve positioned around the clamp assembly, wherein the clamp assembly is configured to rotate with the oilfield tubular and with respect to the outer sleeve.
A control system for a tong for a drilling rig includes a tong motor control valve that is selectively actuatable to cause rotation of the tong in a first direction or in a second direction, a run/pull mode selector configured to actuate between a first configuration for running tubulars into a well and a second configuration for pulling tubulars from the well, a rotation speed selector configured to actuate between a high-speed setting configured to cause the tong to be driven to rotate at a first speed, and a low-speed setting configured to cause the tong to be driven to rotate at a second speed, and a rotation change control device configured to selectively prevent or permit actuation of the tong motor control valve based on the configuration of the run/pull mode selector and the setting of the rotation speed selector.
A control system for a tong for a drilling rig includes a tong motor control valve that is selectively actuatable to cause rotation of the tong in a first direction or in a second direction, a run/pull mode selector configured to actuate between a first configuration for running tubulars into a well and a second configuration for pulling tubulars from the well, a rotation speed selector configured to actuate between a high-speed setting configured to cause the tong to be driven to rotate at a first speed, and a low-speed setting configured to cause the tong to be driven to rotate at a second speed, and a rotation change control device configured to selectively prevent or permit actuation of the tong motor control valve based on the configuration of the run/pull mode selector and the setting of the rotation speed selector.
A centralizer assembly installed on a casing section. A bow spring assembly having bow spring members is installed around the outer surface of the casing section and can rotate about the outer surface of the casing section. At least one portion of the casing section is swaged to increase the outer diameter of that section. Bow spring heel supports prevent bow spring members from contacting the outer surface of the central casing section when compressed. Non-abrasive materials prevent damage to wellhead or other polished bore receptacles.
Methods and systems for controlling a stand-building process of which the method includes engaging a first tubular using an elevator, hoisting the first tubular by raising the elevator, lowering the first tubular into a spider by lowering the elevator, engaging the first tubular using the spider, disengaging the first tubular from the elevator after engaging the first tubular using the spider, engaging a second tubular using the elevator, hoisting and lowering the second tubular into engagement with the first tubular, connecting together the first and second tubulars, and disengaging the spider from the first tubular after connecting together the first and second tubulars. At all times during the stand-building process, a sequential step control system locks an open/close control of the elevator control, or locks an open/close control of the spider control, or locks both, depending on a step of the stand-building process being performed.
A portable apparatus for vertically positioning tubulars in a mousehole of a drilling rig includes a main body housing a winch and an anchor point. The main body is configured to be radially aligned with the mousehole. The apparatus also includes a float assembly which is suspended within the mousehole below the main body and a cable wound onto the winch. The cable extends downward into the mousehole traversing the mousehole at the float assembly and then extends upward to and attached to the anchor point on the main body.
E21B 19/084 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods with flexible drawing means, e.g. cables
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrickApparatus for feeding the rods or cables
A method including acquiring measurements representing torque applied to a connection between a first tubular and a second tubular, a rotational position of the first tubular relative to the second tubular, or both, obtaining a plurality of make-up parameters representing conditions under which the connection is fully made, generating a plurality of rules for connection evaluation based on the make-up parameters, and automatically evaluating the connection using a computer. Automatically evaluating includes applying machine learning, the plurality of rules, or a combination thereof to a dataset of the measurements. The method also includes recommending accepting or rejecting the connection based on the automatic evaluation.
G01N 19/08 - Detecting presence of flaws or irregularities
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
27.
Clamp-on single joint manipulator for use with single joint elevator
An apparatus for assembling a tubular string includes a rig drilling bail, a joint bail extender, and a device. The joint bail extender is rigidly coupled to the rig drilling bail. The device is coupled to the first joint bail extender and configured to engage a tubular segment.
E21B 17/042 - CouplingsJoints between rod and bit, or between rod and rod threaded
E21B 19/087 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods by means of a swinging arm
A load transfer system includes a load transfer bushing having a first and second arcuate segments configured to engage a load surface of a tubular or of a collar connected to the tubular, and an elevator configured to receive the load transfer bushing. Moving the elevator from its closed position to its open position while the elevator engages the load transfer bushing moves the first and second arcuate segments apart, permitting the elevator and the load transfer bushing to be received around the tubular. Moving the elevator from the opened position to the closed position with the load transfer bushing and elevator surrounding the tubular forms an axial engagement load surface for the load surface of the tubular or the collar. The load transfer bushing is disengageable from the elevator.
Oilfield power tools, namely, a casing and drill pipe circulation and flowback tool for circulating fluid into and out of oilfield casing pipes and drill pipes as part of a drilling process
Oilfield power tools, namely, a casing and drill pipe circulation and flowback tool for circulating fluid into and out of oilfield casing pipes and drill pipes as part of a drilling process
A tubular connecting system includes a tong configured to apply a torque on an upper tubular, to torque a connection of the upper tubular to a lower tubular, a torque linkage extending at least partially vertically from the tong, the torque linkage being configured to transmit a force or force-pair, or pure torque, generated by the tong applying the torque to the upper tubular, a transmission plate removably coupled to the torque linkage so as to transmit linear forces thereto, therefrom, or both, the transmission plate being configured to receive the lower tubular therethrough, and a landing plate removably coupled to the transmission plate and configured to engage the lower tubular. The landing plate is configured to counteract the torque as it is applied to the lower tubular by the tong.
Systems, methods, and computer-readable media for mitigating collision occurrences on a drilling rig, of which an example of the method includes associating ultra wide band (UWB) tags with pieces of rig equipment and rig personnel. The tags are configured to communicate with one or more anchors. The method also includes determining interlock rules associated with each of the pieces of rig equipment, monitoring positions of the pieces of rig equipment and the rig personnel using the tags, in real-time, determining that one or more of the interlock rules are violated by a position of one or more of the pieces of rig equipment, rig personnel, or both, and, in response to determining that the one or more of the interlock rules are violated, at least partially disabling operation of one or more of the pieces of rig equipment.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
G01S 5/14 - Determining absolute distances from a plurality of spaced points of known location
E21B 41/00 - Equipment or details not covered by groups
F16P 3/14 - Safety devices acting in conjunction with the control or operation of a machineControl arrangements requiring the simultaneous use of two or more parts of the body with means, e.g. feelers, which in case of the presence of a body part of a person in or near the danger zone influence the control or operation of the machine the means being photocells or other devices sensitive without mechanical contact
G08B 21/02 - Alarms for ensuring the safety of persons
A pipe racking system and method, of which the pipe racking system includes a vertical column extending upwards from a rig floor, a main arm that is movable vertically along the column, a gripper connected to a distal end of the main arm and movable therewith, and an elevator including a plurality of slips configured to engage an outer diameter surface of a tubular and support a weight of the tubular by gripping the outer surface of the tubular. The elevator is suspended from the gripper or a distal end of the main arm via one or more suspension arms. The system also includes one or more guide arms connected to the vertical column. The one or more guide arms are configured to maintain a vertical orientation of the tubular.
A tubular handling system and method, of which the system includes a power tong configured to engage and rotate an add-on tubular by applying a torque thereto, the power tong defining a central opening configured to receive the add-on tubular therethrough, a spider disposed at a rig floor, the spider being configured to support a tubular string, a lifting assembly coupled with the power tong and configured to move the power tong vertically with respect to the tubular string and the spider, and a control line guide coupled to the power tong. The control line guide is movable between an extended position in which the control line guide is configured to guide a control line into close proximity to the add-on tubular, and a retracted position in which the control line guide is configured to maintain a lateral control line clearance gap between the control line and the add-on tubular.
A gripping tool for gripping oilfield tubulars includes a gripping element having a substrate, and at least one gripping surface configured to engage an oilfield tubular, the at least one gripping surface being formed on the gripping element. The at least one gripping surface includes a coating on an outer surface of the substrate, the coating includes a carrier and a plurality of particles at least partially embedded in the carrier. The particles each have a hardness that is greater than a hardness of the carrier and a base metal of the gripping element, and the particles extend outward from the carrier and are configured to engage a structure that is gripped by the gripping tool.
C23C 28/04 - Coating for obtaining at least two superposed coatings either by methods not provided for in a single one of main groups , or by combinations of methods provided for in subclasses and only coatings of inorganic non-metallic material
C23C 8/02 - Pretreatment of the material to be coated
C23C 8/34 - Solid state diffusion of only non-metal elements into metallic material surfacesChemical surface treatment of metallic material by reaction of the surface with a reactive gas, leaving reaction products of surface material in the coating, e.g. conversion coatings, passivation of metals using gases more than one element being applied in more than one step
C23C 8/36 - Solid state diffusion of only non-metal elements into metallic material surfacesChemical surface treatment of metallic material by reaction of the surface with a reactive gas, leaving reaction products of surface material in the coating, e.g. conversion coatings, passivation of metals using gases using ionised gases, e.g. ionitriding
C23C 18/32 - Coating with one of iron, cobalt or nickelCoating with mixtures of phosphorus or boron with one of these metals
C23C 24/08 - Coating starting from inorganic powder by application of heat or pressure and heat
C23C 28/00 - Coating for obtaining at least two superposed coatings either by methods not provided for in a single one of main groups , or by combinations of methods provided for in subclasses and
C23C 8/58 - Solid state diffusion of only non-metal elements into metallic material surfacesChemical surface treatment of metallic material by reaction of the surface with a reactive gas, leaving reaction products of surface material in the coating, e.g. conversion coatings, passivation of metals using liquids, e.g. salt baths, liquid suspensions more than one element being applied in more than one step
C23C 18/16 - Chemical coating by decomposition of either liquid compounds or solutions of the coating forming compounds, without leaving reaction products of surface material in the coatingContact plating by reduction or substitution, i.e. electroless plating
C25D 15/00 - Electrolytic or electrophoretic production of coatings containing embedded materials, e.g. particles, whiskers, wires
36.
SYSTEMS AND METHODS FOR DETERMINING CONNECTION INTEGRITY BETWEEN TUBULARS
A method for determining an integrity of a connection includes applying a high-contrast material to a connection between a first tubular and a second tubular. A torque is applied to the first tubular. Applying the torque to the first tubular includes rotating the first tubular relative to the second tubular to establish the connection. A change in pattern of the high-contrast material in analyzed, while the torque is applied to the first tubular, using a strain detection tool that does not contact the connection. A strain at the connection is determined, based at least partially upon analyzing the change in pattern of the high-contrast material. An integrity of the connection is determined, based at least partially upon the strain.
G01L 5/24 - Apparatus for, or methods of, measuring force, work, mechanical power, or torque, specially adapted for specific purposes for determining value of torque or twisting moment for tightening a nut or other member which is similarly stressed
F16L 15/08 - Screw-threaded jointsForms of screw-threads for such joints with supplementary elements
An apparatus and method for reducing torque in a drill string, in which the apparatus includes a first clamp assembly including a plurality of arcuate clamp segments that are pivotally connected together, the plurality of arcuate clamp segments being configured to be positioned around and secured to an oilfield tubular so as to be rotationally fixed to the oilfield tubular, and an outer sleeve positioned around the first clamp assembly. The outer sleeve includes at least two sleeve segments assembled together to form a generally cylindrical sleeve around the first clamp assembly, and the first clamp assembly is configured to rotate with the oilfield tubular and with respect to the outer sleeve.
An apparatus and method for reducing torque in a drill string, in winch the apparatus includes a first clamp assembly including a plurality of arcuate clamp segments that are pivotallv connected together, the plurality of arcuate clamp segments being configured to be positioned around and secured to an oilfield tubular so as to be rotationally fixed to the oilfield tubular, and an outer sleeve positioned around the first clamp assembly. The outer sleeve includes at least two sleeve segments assembled together to form a generally cylindrical sleeve around the first clamp assembly, and the first clamp assembly is configured to rotate with the oilfield tubular and with respect to the outer sleeve.
A tubular gripping assembly includes a power tong housing configured to actuate between an open position and a closed position, one or more valves coupled to the power tong housing, an inflatable bladder apparatus coupled to an inner surface of the power tong housing and configured to grip a tubular member when the power tong housing is in the closed position and the inflatable bladder apparatus is inflated, a latch mechanism configured to secure the power tong housing in the closed position and configured to allow the power tong housing to actuate to the open position, and a remote-controller device in wireless communication with the one or more valves. The remote-controller device is configured to control the power tong housing, the inflatable bladder apparatus, and the latch mechanism.
E21B 19/06 - Elevators, i.e. rod- or tube-gripping devices
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
E21B 19/24 - Guiding or centralising devices for drilling rods or pipes
Oilfield machines, namely, plugs used to provide a temporary barrier inside a wellbore in order to separate stages or zones during stimulation or fracturing operations
41.
Method and apparatus for automated connection of a fluid conduit
A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement or hydraulic fracturing head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet including, without limitation, when the device is positioned at an elevated location above a rig floor.
09 - Scientific and electric apparatus and instruments
37 - Construction and mining; installation and repair services
Goods & Services
Computer software for oilfield tubular connection systems, namely, software for use in drilling rigs for purposes of monitoring a process of connecting two drill pipes or casing segments, determining if a connection therebetween was properly made, and diagnosing the cause of a connection that was not properly made Oilfield tubular connection services, namely, monitoring a process for connecting two drill pipes or casing segments together, determining if a connection therebetween was properly made, and diagnosing the cause of a connection that was not properly made
43.
Large diameter tubular lifting apparatuses and methods
A lifting elevator includes a first elevator segment having a first plurality of slips, a second elevator segment having a second plurality of slips, and a hinge. The first elevator segment and the second elevator segment each have a swept angle of about 180°, and each of the first plurality of slips and the second plurality of slips includes a die configured to grip an external surface of a pipe.
The present disclosure provides a modular insert float system and method that can be inserted into a casing and attached to the casing internal surface by internal slips and sealing components. The system is modular in that three main components: an upper valve assembly, a lower valve assembly, and a pair of casing anchor and seal assemblies along with top and bottom shoes form a kit that can be used for virtually any casing of a given size regardless of the threads, casing material grades, length of joint, or other variations. Further, the system allows for insertion of the casing into the wellbore without damaging the formation from forcing wellbore fluid into the formation and causing the loss of wellbore fluid in the wellbore.
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 33/128 - PackersPlugs with a member expanded radially by axial pressure
E21B 34/00 - Valve arrangements for boreholes or wells
A tong and method, in which the tong includes a first plate, and a gear that is rotatable relative to the first plate. The gear defines a slot laterally therethrough. An inner surface of the gear includes at least three cam surface. The tong also includes at least three jaws coupled to the first plate such that the at least three jaws are radially movable with respect to the first plate and are prevented from circumferential movement with respect thereto. The at least three jaws are engageable with the at least three cam surfaces such that rotation of the gear relative to the first plate causes the at least three jaws to move in a radial direction between an extended position and a retracted position.
A tong and method, in which the tong includes a first plate, and a gear that is rotatable relative to the first plate. The gear defines a slot laterally therethrough. An inner surface of the gear includes at least three cam surface. The tong also includes at least three jaws coupled to the first plate such that the at least three jaws are radially movable with respect to the first plate and are prevented from circumferential movement with respect thereto. The at least three jaws are engageable with the at least three cam surfaces such that rotation of the gear relative to the first plate causes the at least three jaws to move in a radial direction between an extended position and a retracted position.
A connector tool is used to direct fluids from a lifting assembly into a bore of a downhole tubular. The connector tool includes a body having an upper end and a lower end. The upper end is configured to be coupled to the lifting assembly, and the lower end is configured to be coupled to the downhole tubular. A telescopic engagement assembly is coupled to the body and configured to selectively extend and retract a seal assembly disposed at a distal end of the connector tool with a proximal end of the downhole tubular. A pump is coupled to the lifting assembly such that rotational movement from a component of the lifting assembly directs fluid to extend and retract the telescopic engagement assembly.
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
E21B 19/06 - Elevators, i.e. rod- or tube-gripping devices
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
A connector tool is used to direct fluids from a lifting assembly into a bore of a downhole tubular. The connector tool includes a body having an upper end and a lower end. The upper end is configured to be coupled to the lifting assembly, and the lower end is configured to be coupled to the downhole tubular. A telescopic engagement assembly is coupled to the body and configured to selectively extend and retract a seal assembly disposed at a distal end of the connector tool with a proximal end of the downhole tubular. A pump is coupled to the lifting assembly such that rotational movement from a component of the lifting assembly directs fluid to extend and retract the telescopic engagement assembly.
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
An apparatus for gripping a tubular includes a body. A slip carrier is coupled to an inner surface of the body. The slip carrier is configured to pivot between an open position and a closed position. A tubular is configured to be introduced laterally into the body when the slip carrier is in the open position. A slip is coupled to the slip carrier. The slip is configured to move radially between a first position that is spaced apart from the tubular and a second position that contacts and grips the tubular.
An apparatus for gripping a tubular includes a body. A slip carrier is coupled to an inner surface of the body. The slip carrier is configured to pivot between an open position and a closed position. A tubular is configured to be introduced laterally into the body when the slip carrier is in the open position. A slip is coupled to the slip carrier. The slip is configured to move radially between a first position that is spaced apart from the tubular and a second position that contacts and grips the tubular.
A tubular handling system and method, of which the tubular handling system includes a power tong configured to engage and rotate an add-on tubular by applying a torque thereto, the power tong defining a central opening configured to receive the add-on tubular therethrough, a spider disposed at a rig floor, the spider being configured to support a tubular string, a lifting assembly coupled with the power tong and configured to move the power tong vertically with respect to the tubular string and the spider, and a torque-measuring device configured to measure a reactionary torque transmitted from the power tong to the lifting assembly.
A tubular handling system and method, of which the tubular handling system includes a power tong configured to engage and rotate an add-on tubular by applying a torque thereto, the power tong defining a central opening configured to receive the add-on tubular therethrough, a spider disposed at a rig floor, the spider being configured to support a tubular string, a lifting assembly coupled with the power tong and configured to move the power tong vertically with respect to the tubular string and the spider, and a torque-measuring device configured to measure a reactionary torque transmitted from the power tong to the lifting assembly.
E21B 7/20 - Driving or forcing casings or pipes into boreholes, e.g. sinkingSimultaneously drilling and casing boreholes
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
A tong for applying torque to a tubular and a method of using a tong, of which the tong includes a rotary ring defining an inner profile through which the tubular is received, the inner profile defining a plurality of pockets extending radially outward and a plurality of cam surfaces circumferentially between the plurality of pockets, and a plurality of engaging members disposed within the rotary ring. The plurality of engaging members are movable from a retracted position at least partially in the plurality of pockets to an engaging position in which the plurality of engaging members are positioned along the plurality of cam surfaces. The tong also includes a plurality of cam followers extending through the rotary ring, and a worm drive including a helical ridge. The plurality of cam followers engage the helical ridge so as to transmit a substantially tangential force to the rotary ring.
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
F16H 1/16 - Toothed gearings for conveying rotary motion without gears having orbital motion involving only two intermeshing members with non-parallel axes comprising worm and worm-wheel
54.
Method and apparatus to position and protect control lines being coupled to a pipe string on a rig
An apparatus to attach a control line to a tubular member, in which the apparatus includes a control line arm having a first control line guide coupled thereto, and a base having a second control line guide coupled thereto, with the control line arm coupled to the base and movable with respect to the base. The control line arm may be movable between a raised position and a collapsed position with respect to the base, and the control line arm may be at least one of slidably coupled and rotatably coupled to the base.
E21B 33/072 - Well headsSetting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells for cable-operated tools
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
A tubular gripping assembly includes a power tong housing configured to actuate between an open position and a closed position. An inflatable bladder apparatus is coupled to an inner surface of the power tong housing and configured to grip a tubular member when the power tong housing is in the closed position and the inflatable bladder apparatus is inflated. A latch mechanism, operative in response to a remote control signal provided through a mechanized docking and undocking fluid connector, is configured to secure the power tong housing in the closed position and to allow the power tong housing to actuate to the open position.
A tubular gripping assembly includes a power tong housing configured to actuate between an open position and a closed position. An inflatable bladder apparatus is coupled to an inner surface of the power tong housing and configured to grip a tubular member when the power tong housing is in the closed position and the inflatable bladder apparatus is inflated. A latch mechanism, operative in response to a remote control signal provided through a mechanized docking and undocking fluid connector, is configured to secure the power tong housing in the closed position and to allow the power tong housing to actuate to the open position.
E21B 19/06 - Elevators, i.e. rod- or tube-gripping devices
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
A pipe wrench for making-up or breaking-out a threaded connection between a first tubular member and a second tubular member includes an upper wrench assembly with a pair of upper jaw assemblies configured to grip the first tubular member and a lower wrench assembly with a pair of lower jaw assemblies configured to grip the second tubular member. The upper and lower wrench assemblies are concentrically constrained, axially overlap, and radially engage with one another. Each of the upper and lower wrench assemblies independently includes a frame with a curved segment containing an arc at an angle of about 160 to about 200. The upper and lower wrench assemblies are configured to rotate the first tubular member relative to the second tubular member and can have an angle of rotation in a range from about 75 to about 180.
An apparatus for assembling a tubular string includes a rig drilling bail, a joint bail extender, and a device. The joint bail extender is rigidly coupled to the rig drilling bail. The device is coupled to the first joint bail extender and configured to engage a tubular segment.
E21B 19/00 - Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrickApparatus for feeding the rods or cables
E21B 19/06 - Elevators, i.e. rod- or tube-gripping devices
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
E21B 17/042 - CouplingsJoints between rod and bit, or between rod and rod threaded
E21B 19/087 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods by means of a swinging arm
A pipe wrench for making-up or breaking-out a threaded connection between a first tubular member and a second tubular member includes an upper wrench assembly with a pair of upper jaw assemblies configured to grip the first tubular member and a lower wrench assembly with a pair of lower jaw assemblies configured to grip the second tubular member. The upper and lower wrench assemblies are concentrically constrained, axially overlap, and radially engage with one another. Each of the upper and lower wrench assemblies independently includes a frame with a curved segment containing an arc at an angle of about 160° to about 200°. The upper and lower wrench assemblies are configured to rotate the first tubular member relative to the second tubular member and can have an angle of rotation in a range from about 75° to about 180°.
An apparatus for assembling a tubular string includes a rig drilling bail, a joint bail extender, and a device. The joint bail extender is rigidly coupled to the rig drilling bail. The device is coupled to the first joint bail extender and configured to engage a tubular segment.
A system and method for installing a tubular in a wellbore, of which the method includes coupling a fluid connector tool to a lifting assembly, coupling a casing fill-up and circulation seal assembly to the fluid connector tool, and coupling two segments of casing together to form a casing string. At least one of the segments of casing is fluidically coupled to the casing fill-up and circulation seal assembly. The method also includes running the casing string into a wellbore, pumping a first fluid from the lifting assembly, through the fluid connector tool and the casing fill-up and circulation seal assembly, and into the casing string as the casing string is run into the wellbore, de-coupling the casing fill-up and circulation seal assembly from the fluid connector tool, and coupling a drill-pipe seal assembly to the fluid connector tool.
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
62.
Combined casing fill-up and drill pipe flowback tool and method
A system and method for installing a tubular in a wellbore, of which the method includes coupling a fluid connector tool to a lifting assembly, coupling a casing fill-up and circulation seal assembly to the fluid connector tool, and coupling two segments of casing together to form a casing string. At least one of the segments of casing is fluidically coupled to the casing fill-up and circulation seal assembly. The method also includes running the casing string into a wellbore, pumping a first fluid from the lifting assembly, through the fluid connector tool and the casing fill-up and circulation seal assembly, and into the casing string as the casing string is run into the wellbore, de-coupling the casing fill-up and circulation seal assembly from the fluid connector tool, and coupling a drill-pipe seal assembly to the fluid connector tool.
A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement or hydraulic fracturing head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet including, without limitation, when the device is positioned at an elevated location above a rig floor.
Systems and methods for preventing improper lifting of tubular members are described, in which sensing devices are used to detect when a tubular reaches a selected position within a lifting device suitable for engagement, and/or to detect when a lifting operation is initiated that would exceed the capacity of a lifting device. Operators are engaged with the tubular member and provided with a preselected force corresponding to the weight of one or more tubular members, such that when the weight of a lifting operation exceeds the preselected force, an audible device may be actuated responsive to sensor output, to immediately alert individuals, such that the improper lifting operation may be halted. Similarly, an audible device may be actuated responsive to sensor output when a tubular member reaches a selected position within the lifting device, such that additional movement may be ceased.
A gripping tool includes a gripping element and at least one gripping surface formed on the gripping element. The at least one gripping surface includes a plurality of teeth extending from the gripping element an outer layer. A method to surface process a gripping surface of a gripping tool includes providing the gripping surface in an environment comprising a source of additive material and heating the gripping surface at a temperature and a time to diffuse the additive material a depth into the gripping surface to form a diffusion layer.
C23C 8/02 - Pretreatment of the material to be coated
C23C 8/34 - Solid state diffusion of only non-metal elements into metallic material surfacesChemical surface treatment of metallic material by reaction of the surface with a reactive gas, leaving reaction products of surface material in the coating, e.g. conversion coatings, passivation of metals using gases more than one element being applied in more than one step
C23C 8/36 - Solid state diffusion of only non-metal elements into metallic material surfacesChemical surface treatment of metallic material by reaction of the surface with a reactive gas, leaving reaction products of surface material in the coating, e.g. conversion coatings, passivation of metals using gases using ionised gases, e.g. ionitriding
C23C 28/00 - Coating for obtaining at least two superposed coatings either by methods not provided for in a single one of main groups , or by combinations of methods provided for in subclasses and
C23C 28/04 - Coating for obtaining at least two superposed coatings either by methods not provided for in a single one of main groups , or by combinations of methods provided for in subclasses and only coatings of inorganic non-metallic material
A centralizer assembly installed on a casing section. A bow spring assembly having bow spring members is installed around the outer surface of the casing section and can rotate about the outer surface of the casing section. A portion of the casing section that is aligned with the bow spring assembly is swaged to increase the outer diameter of that section. Bow spring heel supports prevent bow spring members from contacting the outer surface of the central casing section when compressed. Non-abrasive materials prevent damage to wellhead or other polished bore receptacles.
A tubular handling system and method for handling tubulars are provided. The tubular handling system includes a load transfer sleeve. The load transfer sleeve includes a body defining an inner diameter and a tapered bowl extending outward from the inner diameter, with the bowl defining a landing surface. The load transfer sleeve also includes a load bushing comprising a plurality of load bushing segments that are slidable along the bowl. The load bushing radially expands and contracts by axial translation of the plurality of load bushing segments relative to the body. Further, the plurality of load bushing segments each define an axial engagement surface configured to engage an upset of a tubular and a landing surface that engages the landing surface of the bowl when the axial engagement surface engages the upset.
Systems, apparatus and methods are usable for automatically engaging and setting slips of an automatic slip setting apparatus about a tubular, when the automatic slip setting apparatus is properly positioned relative to a desired section of the tubular for gripping, lifting and/or holding, and installing and/or removing the tubular, in or out from a wellbore, while preventing slippage and/or dropping of the tubular. The automatic slip setting apparatus is usable with an elevator or spider assembly, each comprising a main body having a central opening extending therethrough, a plurality of slips, and a yoke. An arm assembly, connected to the elevator or spider assembly, moves when contacted by a tubular moving through the central opening, and a latching member, which is connected to the yoke, can be moved by the arm assembly, thereby causing the plurality of slips to move to a closed position for gripping the tubular.
A lifting elevator includes a first elevator segment having a first plurality of slips, a second elevator segment having a second plurality of slips, and a hinge. The first elevator segment and the second elevator segment each have a swept angle of about 180°, and each of the first plurality of slips and the second plurality of slips includes a die configured to grip an external surface of a pipe.
A drilling rig with mini-stabilizer tool for connecting to a measurement while drilling (MWD) system. The mini-stabilizer tool centralizes components in the wellbore for a more accurate measurement to protect measurement while drilling components from wear on shoulders of the measurement while drilling components. The mini-stabilizer tool accomplishes wear prevention by positioning the measurement while drilling components away from edges of the wellbore.
E21B 10/46 - Drill bits characterised by wear resisting parts, e.g. diamond inserts
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
71.
APPARATUS AND METHOD FOR REDUCING TORQUE ON A DRILL STRING
Apparatus for reducing torque on a drill string includes a first bearing assembly, a second bearing assembly, and a bearing sleeve. The first and second bearing assemblies are disposed on and clamped onto a tubular portion of a drill pipe of the drill string, and each include a first and second section. The bearing sleeve is disposed on the drill pipe such that the bearing sleeve is maintained in an axial position relative to the drill pipe by the first bearing assembly and the second bearing assembly. Each of the first and second bearing assemblies have a first diameter portion and a second diameter portion that is smaller than the first diameter portion. The second diameter portion of the first bearing assembly and the second diameter portion of the second bearing assembly are disposed adjacent to each other and the bearing sleeve is disposed around the adjacent second diameter portions.
The present disclosure relates to a system and a method to grip a tubular member and sense wear for a pipe handling apparatus. The system includes a pipe handling apparatus having a bore formed therein with an axis defined therethrough, a pipe guide disposed adjacent to an opening of the bore of the pipe handling apparatus, and a wear sensor coupled to the pipe guide.
A bidirectional stabilizer which reduces impact damage while rotating into and out of a wellbore. The bidirectional stabilizer can be coupled on a first end to a drill string and on a second end to a drill bit. The bidirectional stabilizer can have an annulus configured for maximum wellbore fluid flow. A cutting portion can be formed on a shaft with a plurality of helical blades between the first shaft end and the second shaft end. The plurality of helical blades of the cutting portion can be on a first plane and a plurality of cutting nodes can be on a second plane for smoothing a wellbore. The plurality of cutting nodes can have at least one impact arrestor mounted directly adjacent each cutting node.
A tubular support assembly, method, and offshore drilling rig. The tubular support assembly includes a spider configured to support a tubular received therethrough, and a rotary table that supports the spider and transmits a vertical load applied to the spider to a rig floor. The tubular support assembly also includes a load cell configured to measure the vertical load.
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
E21B 19/09 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods specially adapted for drilling underwater formations from a floating support using heave compensators supporting the drill string
E21B 15/02 - Supports for the drilling machine, e.g. derricks or masts specially adapted for underwater drilling
B63B 35/44 - Floating buildings, stores, drilling platforms, or workshops, e.g. carrying water-oil separating devices
75.
Bidirectional stabilizer with impact arrestors and blades with wrap angles
A bidirectional stabilizer, which reduces impact damage while rotating into and out of a wellbore. The bidirectional stabilizer can be coupled on a first end to a drill string and on a second end to a drill bit. The bidirectional stabilizer can have an annulus configured for maximum wellbore fluid flow. A cutting portion can be formed on a shaft with a plurality of blades between the first shaft end and the second shaft end. The plurality of blades of the cutting portion can be on a first plane and a plurality of cutting nodes can be on a second plane for smoothing a wellbore. The plurality of blades can have a wrap angle for forming a particle flow path between pairs of the plurality of blades configured with a line of sight parallel to the longitudinal axis.
A load lifting apparatus comprises a first housing, a second housing and a mechanical obstruction structure(s). The first housing is sized to slide over an upset tubular having a given diameter, wherein the first housing comprises the mechanical obstruction structure(s) that is designed to move radially inward when engaged with the second housing. The compressed internal diameter of the mechanical obstruction structure(s) can contact the upset tubular, wherein the upset tubular can then be supported by the mechanical obstruction structure(s) and the second housing, for safely lifting the upset tubular.
Methods and apparatus for running a tubular into a wellbore. The method includes attaching a first member of a lifting coupling to a first tubular, and attaching a second member of the lifting coupling to a second tubular. The second tubular extends downward through an opening of a rotary station. The method also includes connecting together the first and second members of the lifting coupling, such that a weight of the second tubular is transmitted via the lifting coupling to the first tubular. The method further includes lowering the lifting coupling, the second tubular, and at least a portion of the first tubular through the opening, and disconnecting the second member from the first member. The method additionally includes moving the second member of the lifting coupling and the second tubular laterally, away from the opening.
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
E21B 15/02 - Supports for the drilling machine, e.g. derricks or masts specially adapted for underwater drilling
Methods and apparatus for running a tubular into a wellbore. The method includes attaching a first member of a lifting coupling to a first tubular, and attaching a second member of the lifting coupling to a second tubular. The second tubular extends downward through an opening of a rotary station. The method also includes connecting together the first and second members of the lifting coupling, such that a weight of the second tubular is transmitted via the lifting coupling to the first tubular. The method further includes lowering the lifting coupling, the second tubular, and at least a portion of the first tubular through the opening, and disconnecting the second member from the first member. The method additionally includes moving the second member of the lifting coupling and the second tubular laterally, away from the opening.
A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet of a cement head including, without limitation, when the cement head is positioned at an elevated location above a rig floor.
A drilling rig with bidirectional dual eccentric reamer which forms a larger wellbore than originally drilled and larger than the drill bit diameter. The bidirectional dual eccentric reamer has a shaft with a longitudinal axis supporting a plurality of reamer portions. The reamer portions have a plurality of helical blades of varying thicknesses. The plurality of helical blades can have a plurality of cutting nodes and cutting inserts. The plurality of helical blades have a center of eccentric rotation which is offset from the longitudinal axis, thereby creating an eccentric rotation which allows for the formation of a larger wellbore than originally drilled and larger than the drill bit diameter.
E21B 19/084 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods with flexible drawing means, e.g. cables
E21B 10/26 - Drill bits with leading portion, i.e. drill bits with a pilot cutterDrill bits for enlarging the borehole, e.g. reamers
A remotely operated lifting top drive cement head has a high tensile strength and the ability to swivel or rotate. The cement head permits selective launching of darts, setting plugs, balls or other objects which can be held in place within the cement head without being damaged or washed away by slurry flow, but which can be launched as desired. The cement head can be remotely operated without requiring personnel to be lifted off the rig floor to actuate the tool or observe tool status.
A bidirectional stabilizer and a drill string wherein the bidirectional stabilizer reduces motion while rotating into and out of a wellbore. The bidirectional stabilizer can be coupled on a first shaft end to the drill string and on a second shaft end to a bottom hole assembly or other downhole equipment. The bidirectional stabilizer can have an annulus configured for maximum wellbore fluid flow. A cutting portion can be formed on a shaft with a plurality of blades between the first shaft end and the second shaft end. The plurality of blades of the cutting portion can be on a first plane and a plurality of cutting nodes can be on a second plane for smoothing a wellbore.
A system for installing control line secured to a tubular string suspended in a borehole includes a first arm having a pivotally secured first end about which a second end is rotatable with a generally vertical plane, and a second arm having a first end pivotally coupled to the second end of the first arm and a second end coupled to a control line retainer. The second arm slidably engages a stationary pathway at a position intermediate the first end and the second end of the second arm. The system also includes one or more cylinders for rotating the first arm and for translating and rotating the second arm within the vertical plane to move the control line retainer along a generally vertical path along the tubular string.
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
E21B 33/072 - Well headsSetting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells for cable-operated tools
An elevator to manipulate a tubular segment includes an elevator body with a bore formed therethrough having an axis therein, the elevator body including a plurality of openings extending from an outer surface of the elevator body to the bore of the elevator body, and a base member coupled to a bottom surface of the elevator body, the base member having a guide portion that directs the tubular segment into the bore of the elevator body. The elevator also includes a plurality of slip assemblies disposed inside the plurality of openings and coupled to the elevator body, each of the plurality of slip assemblies including an actuator body coupled to the elevator body, a slip, the slip including an engagement surface disposed orthogonal to the axis of the bore of the elevator body that engages the tubular segment.
E21B 19/06 - Elevators, i.e. rod- or tube-gripping devices
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
An elevator to manipulate a tubular segment includes an elevator body with a bore formed therethrough having an axis therein, the elevator body including a first elevator segment and a second elevator segment, in which each of the first elevator segment and the second elevator segment includes a plurality of openings extending from an outer surface of the elevator body to the bore of the elevator body. The elevator also includes a plurality of slip assemblies disposed inside the plurality of openings of the first elevator segment and the second elevator segment and coupled to the elevator body, each of the plurality of slip assemblies including a slip, the slip including an engagement surface disposed orthogonal to the axis of the bore of the elevator body that engages the tubular segment.
B66C 1/48 - Gripping members engaging only the external or internal surface of the articles and applying frictional forces to vertical edge portions of sheets, tubes, or like thin or thin-walled articles
B23P 19/04 - Machines for simply fitting together or separating metal parts or objects, or metal and non-metal parts, whether or not involving some deformationTools or devices therefor so far as not provided for in other classes for assembling or disassembling parts
A centralizer assembly having a tubular body member with upper and lower channels extending around the external surface of said central tubular body member. A bow spring assembly having bow spring members is installed around the outer surface of the tubular body member and can rotate about the outer surface of the central tubular body member. Bow spring heel supports prevent the bow spring members from contacting the outer surface of the central tubular member when compressed. Non-abrasive materials prevent damage to wellhead or other polished bore receptacles. A robust bolster frame protects the centralizer assembly during shipping, storage or other periods of non-use.
A lifting elevator includes a first elevator segment having a first plurality of slips, a second elevator segment having a second plurality of slips, and a hinge. The first elevator segment and the second elevator segment each have a swept angle of about 180°, and each of the first plurality of slips and the second plurality of slips includes a die configured to grip an external surface of a pipe.
37 - Construction and mining; installation and repair services
Goods & Services
machines and machine tools, namely, Control Line Manipulator Arm, namely, combination of rotating Control Line Sleeve Protector and Control Line Pusher Arm for handling and installing control lines in an oil and gas related well leasing of machines and machine tools, namely, Control Line Manipulator Arm, namely, combination of rotating Control Line Sleeve Protector and Control Line Pusher Arm for handling and installing control lines in an oil and gas related well
A bidirectional dual eccentric reamer which can form a larger wellbore than originally drilled and a wellbore larger than the drill bit diameter. The bidirectional dual eccentric reamer can have a shaft with a longitudinal axis supporting a plurality of reamer portions. The reamer portions have a plurality of helical blades of varying thicknesses. The plurality of helical blades can have a plurality of cutting nodes and cutting inserts. The plurality of helical blades can have a center of eccentric rotation which is offset from the longitudinal axis, thereby creating an eccentric rotation. This allows for the formation of a larger wellbore than originally drilled and a wellbore larger than the drill bit diameter.
A power tong assembly includes a power tong and a speed limiting system operably coupled to the power tong. The power tong is configured to grip and rotate a tubular segment in a first direction to make-up a threaded connection with the tubular segment and in a second direction to break-out the threaded connection with the tubular segment. The speed limiting system is configured to selectively allow the power tong to rotate the tubular segment in one of the first direction and the second direction at a maximum speed while limiting the power tong to rotate the tubular segment in the other of the first direction and the second direction below the maximum speed.
B25B 23/14 - Arrangement of torque limiters or torque indicators in wrenches or screwdrivers
F16L 15/00 - Screw-threaded jointsForms of screw-threads for such joints
G01L 5/24 - Apparatus for, or methods of, measuring force, work, mechanical power, or torque, specially adapted for specific purposes for determining value of torque or twisting moment for tightening a nut or other member which is similarly stressed
A mini-stabilizer tool for connecting to a measurement while drilling (MWD) system. The mini-stabilizer tool centralizes components in the wellbore for a more accurate measurement to protect measurement while drilling components from wear on shoulders of the measurement while drilling components. The mini-stabilizer tool accomplishes wear prevention by positioning the measurement while drilling components away from edges of the wellbore.
An elevator, apparatus, and method for handling a tubular. The apparatus includes a body defining at least a portion of a tapered bowl. The apparatus also includes a plurality of slips disposed at least partially within the bowl and configured to slide along a surface of the bowl. Each of the slips includes a radial engaging surface configured to engage an outer diameter of a tubular, and a tapered engaging surface configured to engage a tapered section of the tubular.
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
An apparatus for handling one or more tubulars. The apparatus may include a body defining at least a portion of a tapered bowl. A plurality of slips may be disposed at least partially within the bowl and configured to slide along a surface of the bowl. Each of the slips may include a radial engaging surface and a tapered engaging surface. The radial engaging surface may have a plurality of gripping structures extending inwardly therefrom that are configured to engage an outer surface of a first tubular having a substantially constant outer diameter. The tapered engaging surface may be configured to engage a tapered outer surface of a second tubular.
An elevator, apparatus, and method for handling a tubular, of which the apparatus includes a body defining at least a portion of a tapered bowl. The apparatus also includes a plurality of slips disposed at least partially within the bowl and configured to slide along a surface of the bowl. Each of the slips includes a radial engaging surface configured to engage an outer diameter of a tubular, and a tapered engaging surface configured to engage a tapered section of the tubular.
An extension assembly, apparatus, and method for racking a tubular are provided. The method includes attaching a coupler to the tubular, such that the coupler receives an end of the tubular. The coupler includes a material that is softer than a material of the end of the tubular, so as to protect a threaded area of the tubular. The method also includes attaching an extension to the coupler such that a height of the tubular plus a height of the extension meets a minimum height of a rack, and positioning the tubular in the rack.
An apparatus for handling one or more tubulars includes a body defining at least a portion of a tapered bowl. A plurality of slips may be disposed at least partially within the bowl and configured to slide along a surface of the bowl. Each of the slips includes a radial engaging surface and a tapered engaging surface. The radial engaging surface may have a plurality of gripping structures extending inwardly therefrom that are configured to engage an outer surface of a first tubular having a substantially constant outer diameter. The tapered engaging surface may be configured to engage a tapered outer surface of a second tubular.
A tubular handling system and method for handling tubulars are provided. The tubular handling system includes a load transfer sleeve. The load transfer sleeve includes a body defining an inner diameter and a tapered bowl extending outward from the inner diameter, with the bowl defining a landing surface. The load transfer sleeve also includes a load bushing comprising a plurality of load bushing segments that are slidable along the bowl. The load bushing radially expands and contracts by axial translation of the plurality of load bushing segments relative to the body. Further, the plurality of load bushing segments each define an axial engagement surface configured to engage an upset of a tubular and a landing surface that engages the landing surface of the bowl when the axial engagement surface engages the upset.
E21B 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
A tubular handling system and method for handling tubulars are provided. The tubular handling system includes a load transfer sleeve. The load transfer sleeve includes a body defining an inner diameter and a tapered bowl extending outward from the inner diameter, with the bowl defining a landing surface. The load transfer sleeve also includes a load bushing comprising a plurality of load bushing segments that are slidable along the bowl. The load bushing radially expands and contracts by axial translation of the plurality of load bushing segments relative to the body. Further, the plurality of load bushing segments each define an axial engagement surface configured to engage an upset of a tubular and a landing surface that engages the landing surface of the bowl when the axial engagement surface engages the upset.
The present invention provides an apparatus and a method for lifting a single joint of pipe. The single joint elevator of the present invention comprises, in one embodiment, a pair of deployable jaws cooperating with a pair of static jaws to secure a pipe within the slot of a generally horseshoe-shaped body. The deployable jaws of the single joint elevator of the present invention may be rotatably deployable or translatably deployable, or both. In one embodiment, each jaw, including the static jaws and the deployable jaws, comprises a pipe slip movably disposed within the jaw to secure a pipe segment within the slot and to self-tighten as the weight of the pipe segment secured within the single joint elevator is transferred to the slips and the jaws.
A method and an apparatus to guide a tubular member are described herein. The apparatus includes a bore with a longitudinal axis extending therethrough and configured to support a tubular member, the apparatus having a first opening formed at a first side thereof, a second opening formed at a second side thereof, and an inner wall extending from the first opening to the second opening. The apparatus further includes a first guiding member disposed adjacent to the first opening of the bowl and a second guiding member disposed adjacent to the second opening of the bowl.
