In accordance with an embodiment of the disclosure, a method includes detecting a first parameter indicative of lateral movement of a top drive system with respect to a rotational axis of the top drive system with a first plurality of sensors and detecting a second parameter indicative of lateral movement of the top drive system with respect to the longitudinal axis of the top drive system with a second plurality of sensors. The first parameter is different from the second parameter. The method also includes transmitting the first parameter and the second parameter to a monitoring system and comparing the first parameter to a first threshold value and comparing the second parameter to a second threshold value with the monitoring system. Detecting the first parameter and the second parameter includes detecting lateral movement of a mud saver valve configured to flow mud through a sealed passage.
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
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
A system includes a top drive system, a swivel joint system coupled to the top drive at a position axially below the top drive system, wherein the swivel joint system comprises a first subunit and a second subunit rotatably coupled together, wherein the first sub unit is coupled to the top drive system, and wherein the swivel joint system is configured to pivot between a first position and a second position, and a tubular gripping system coupled to the second subunit of the swivel joint system.
Certain embodiments include a system having a first grip (100) configured to couple to a first tubular (38), a second grip (102) configured to couple to a second tubular (38), where the first and second tubulars (38) are connected by a threaded connection (52), and a gear assembly (104) coupling the first and second grips (100, 102), wherein the gear assembly (104) has a speed ratio greater than 1.
In accordance with one aspect of the disclosure, a system includes a multiple cement plug launching system (50) having a plug system adapter assembly (56), a first plug assembly (52) comprising a first central passage (118) and a plurality of rupture disks (250), wherein each rupture disk (250) of the plurality of rupture disks (250) occludes a respective one of a plurality of rupture disk ports (252) extending through the first plug assembly (52), and a second plug assembly (54) comprising a second central passage (118), wherein the plug system adapter assembly (56) is coupled to the second plug assembly (54), which is coupled to the first plug assembly (52), such that the plug system adapter assembly (56), the second plug assembly (54), and the first plug assembly (52) are coupled to one another in an axial arrangement.
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes using plugs for isolating cement chargePlugs therefor
09 - Scientific and electric apparatus and instruments
Goods & Services
Software for real-time monitoring and controlling of
drilling processes; software for real-time monitoring and
controlling of surface equipment of a drilling process;
software for real-time monitoring and controlling of a drill
bit of a drilling process; software for real-time monitoring
and controlling optimization of a well profile, rate of
penetration, and bit life wear; software for real-time
monitoring, controlling, and mitigating drill string
anomalies to improve rotary drilling efficiency by
offsetting vibration effects during rotation drilling;
software for real-time monitoring, controlling, and
mitigating stick-slip to improve rotary drilling efficiency
by damping vibration effects during rotation drilling;
computer software for real-time monitoring, controlling, and
mitigating drill string anomalies and stick-slip to improve
life of drill bit, improve rate of penetration in drilling
operation, and auto-tuning variable frequency drive
parameters.
09 - Scientific and electric apparatus and instruments
Goods & Services
Software for real-time monitoring and controlling of
drilling processes; software for real-time monitoring and
controlling of surface equipment of a drilling process and a
drill pipe of a wellbore; software for real-time monitoring
and controlling optimization of a well profile, rate of
penetration, and weight on a drill bit; software for
real-time monitoring, controlling, and planning oscillation
of a drill pipe to reduce friction between the drill pipe
and a wellbore; software for real-time monitoring,
controlling, and planning rocking of a drill pipe to reduce
friction between the drill pipe and a wellbore; software for
real-time monitoring, controlling, and planning drill string
rotation to reduce wellbore and drill pipe friction between
the drill pipe and a wellbore; computer software for
automating drill string rotation, drill pipe oscillation,
and drill pipe rocking, resulting in a reduction of wellbore
friction and drill pipe friction, allowing for an increase
in weight on a drill bit resulting in higher rate of
penetration.
Present embodiments include a first oilfield tubular (102), wherein the first oilfield tubular (100) comprises a threaded box connection at a first axial end (110) of the first oilfield tubular (100), a second oilfield tubular (102), wherein the second oilfield tubular (102) comprises a threaded pin connection at a second axial end (119) of the second oilfield tubular (102), a first flange (104) coupled to the first axial end (110) of the first oilfield tubular (100), wherein the first flange (104) comprises a plurality of apertures (130) arrayed about a first circumference (132) of the first flange (104), and a second flange (106) coupled to the second axial end (119) of the second oilfield tubular (102), wherein the second flange (106) comprises a plurality of recesses (134) arrayed about a second circumference (136) of the second flange (106), wherein each of the plurality of apertures (134) is configured to align with a respective one of the plurality of recesses (0134).
In accordance with one aspect of the disclosure a method includes positioning a cement plug (80) in a casing string (28), completing a casing cementing process, launching the cement plug (80) down the casing string (28), and detecting a magnetic field of an electro-magnetic transmitter (320) coupled to the cement plug (80) or a magnet (302) disposed on an outer surface of the casing string (28) with a magnetic sensor (142) disposed on the outer surface of the casing string (28).
09 - Scientific and electric apparatus and instruments
Goods & Services
Asset management software for real-time monitoring,
controlling, and planning equipment operation and downtime
remotely; maintenance tracking software for real-time
monitoring, controlling, and planning of service events
remotely; predictive health monitoring software for real-
time monitoring, controlling, and planning equipment events
remotely; computer software for providing access to data
collected about status, health, and location of equipment;
wireless transmitters; communication infrastructure, namely,
broadband wireless equipment, namely telecommunications base
station equipment for wireless and fixed networking and
communications applications; shock sensors; vibration
sensors; flow sensors; temperature sensors.
10.
MAGNETIC PIPE JOINT LOCATION DETECTION SYSTEM AND METHOD
A pipe joint location detection system (44) includes a main body (114), at least one magnet (118), and a plurality of magnetic sensors (120). The main body (114) has an annular shape defining a central passage (116), the at least one magnet (118) is coupled to the main body (114), the magnet (118) is configured to output a magnetic field, and the plurality of magnetic sensors (120) is coupled to the main body (114) and disposed about a circumference of the main body (114), wherein each magnetic sensor (120)of the plurality of magnetic sensors (120) is configured to detect a magnetization of a tubular string disposed within the central passage (116). The pipe joint location detection system (44) also includes a memory (222) comprising data stored thereon, wherein the data includes a first magnetization value associated with a first contour of the tubular string and a second magnetization value associated with a second contour of the tubular string, wherein the first contour is different from the second contour.
A system includes a span block (48) configured to couple with an extension (44) from a top drive (42) at a first end (76) of the span block and configured to couple to a tubular (38) at a second end (78) of the span block. The system also includes a sensor block (72) of the span block. The sensor block extends between the first end and the second end of the span block. Moreover, the sensor block is configured to provide an electronic indication of deformation of a portion of the sensor block in response to forces placed on the span block.
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
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
G01L 1/22 - Measuring force or stress, in general by measuring variations in ohmic resistance of solid materials or of electrically-conductive fluidsMeasuring force or stress, in general by making use of electrokinetic cells, i.e. liquid-containing cells wherein an electrical potential is produced or varied upon the application of stress using resistance strain gauges
Embodiments of the present disclosure include a drill pipe guide system (44) having a support structure (52, 54) configured to be positioned on a rig floor (12) or drillship floor, an articulating arm (56) coupled to the support structure, wherein the articulating arm is configured to pivot relative to the support structure, and a clamp(59) coupled to the articulating arm, wherein the clamp is configured to encircle a drill string (38) and limit radial movement of the drill string as the drill string is lowered beneath the rig floor or drillship floor. The embodiments further include a method comprising the steps of positioning an umbilical cable (66) against the drill string (38) with an umbilical guide system (50), encircling the drill string with the clamp (59) of the drill pipe guide system (44); and running the drill string (38) through slips (34) in the drilling rig floor.
Present embodiments are directed to a catwalk system that includes a base, a plurality of columns extending from the base, where each of the plurality of columns is rigid in an erected position, and a carriage and trough assembly configured to translate along the plurality of columns to lift a tubular element from a lowered position to a raised position in a substantially horizontal orientation, where the plurality of columns is configured to remain stationary as the carriage and trough assembly is translated from the lowered position to the raised position.
The present disclosure is directed to systems and methods for rotating a drill string to mitigate stick-slip oscillations. An embodiment includes a method of rotating a drill string driven by a drive system using a control system. The method includes measuring torque values of the drive system with a torque sensor. The method also includes determining a frequency of stick-slip oscillations at the drive system based on the torque values using the control system. The method also includes determining an estimated instantaneous rotational speed of the drive system with the control system based on at least the frequency of stick-slip oscillations and a characteristic impedance of the drill string. The method also includes adjusting the estimated instantaneous rotational speed based on changes in the torque values to define an adjusted estimated instantaneous rotation speed with the control system. The method also includes providing an output signal representing the adjusted estimated instantaneous rotational speed to the drive system. The method also includes controlling rotation of a quill of the drive system based on the output signal.
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
G05D 19/02 - Control of mechanical oscillations, e.g. of amplitude, of frequency, of phase characterised by the use of electric means
15.
SYSTEM AND METHOD WITH TORQUE CONTROL FROM TOP DRIVE
A drilling system includes a multi-function sub (32) configured to be coupled to a top drive (28) of a drilling rig (10) and configured to be coupled to a tubular (44) in order to selectively transfer a torque from the top drive (28) to the tubular (44). The multi-function sub (32) includes a torque sensing component (70) configured to measure the torque provided from the top drive (28) to the tubular (44) via the multi-function sub (32), a clutch (74) configured to suspend a transfer of torque from the top drive (28) to the tubular (44) when the clutch (74) is released, and a clutch actuator communicatively coupled to the torque sensing component (70) and configured to release the clutch (74) when the torque measured by the torque sensing component (70) is greater than a threshold torque value. The multi-function sub (32) also includes a compensator (76) configured to enable the multi-function sub (32) to move the tubular (44) in an axial direction relative to the top drive (28).
The present disclosure is directed to a system for retention of drilling components of a drilling rig that includes a first drilling component (42) with a first retention feature (80), a second drilling component (44) with a second retention feature (84), and a secondary retention device (45). The first drilling component (42) is coupled to the second drilling component (44) and the secondary retention device (45) engages with the first retention feature (80) of the first drilling component (42) and with the second retention feature (84) of the second drilling component (44).
Present embodiments are directed to tubular drive system 40 including a gripping device 42 configured to couple with a length of tubular 38, a rotational system 44 configured to drive rotation of the gripping device 42, and a load support feature 50 coupled to the gripping device 42 and the rotational system 44, wherein the load support feature 50 is configured to support the gripping device 42 and the rotational system 44.
A controlled slip connection system 40 is configured to be coupled between a drill pipe 30 and a directional drilling assembly 32, and the slip connection system 40 is configured to enable continual rotation of the drill pipe 30 while providing a rotationally stationary surface for a mud motor 36 of the directional drilling assembly 32 to react against.
Present embodiments are directed to a system and method for coordinating operation of a gripping device of a top drive system and power slips of a drilling rig to ensure that at least one of the gripping device and the power slips is engaged with a length of tubular and/or a drill string to support weight of the length of tubular and weight of the drill string.
E21B 19/06 - Elevators, i.e. rod- or tube-gripping devices
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
Present embodiments are directed to a drilling fluid management device (80). A containment structure (84) of the drilling fluid management device is capable of engaging and at least partially creating a seal with a drillpipe element (36, 38) or drillpipe handling equipment (32, 34). Further, a suction port structure (86) of the drilling fluid management device extends from the containment structure and includes an opening (208) into the containment structure, wherein the suction port structure is designed to couple with a drilling fluid transport feature (320).
Present embodiments are directed to a top drive movement measurement system having a sensor module configured to be disposed about and couple to a component of a top drive system, a first plurality of sensors of the sensor module, wherein the first plurality of sensors is configured to detect lateral movement of the component of the top drive system, and a second plurality of sensors of the sensor module, wherein the second plurality of sensors is configured to detect one or more compression or tension forces in the component of the top drive system.
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
Present embodiments are directed to a tubular stress measurement system including a first sensor configured to detect a parameter indicative of an axial or circumferential position of the plurality of grapples and a calculation system configured to calculate an internal stress on the tubular based on the parameter.
A conveyor assembly (48) for transporting tubular onto a drilling rig (10) includes a plurality of conveyor sections coupled together end to end. The conveyor sections (50) are configured to receive and transport the tubular. Each of the plurality of conveyor sections (50) includes a conveyor belt (110) having treads (150) for transporting the tubular along the conveyor section (50). The conveyor assembly (48) also includes an actuation assembly (54) configured to transition the plurality of conveyor sections (50) between a first orientation and a second orientation. The conveyor sections (50) are not aligned in the first orientation, and the conveyor sections (50) are substantially aligned in the second orientation.
Present embodiments are directed to a control system including a controller configured to regulate a drilling fluid flow through a pipe element during installation of the pipe element into a wellbore or removal of the pipe element from the wellbore, wherein the controller is configured to regulate the drilling fluid flow based on feedback from one or more sensors of the control system.
Present embodiments are directed to a tubular filling tool 50. In certain embodiments, the tubular filling tool 50 includes a conductor pipe 62 configured to receive a filling fluid flow from a top drive 24 and a diffuser block 66 communicatively coupled to the conductor pipe 62 and configured to receive the filling fluid flow from the conductor pipe 62, wherein the diffuser block 66 comprises a plurality of fluid passages 68 extending to external passages 100 formed in an outer diameter of the diffuser block 66 and configured to facilitate passage of the filling fluid flow to the external passages from within the diffuser block, wherein the external passages 100 are configured to generate a swirl flow pattern in the filling fluid flow during a tubular filling process.
The present disclosure is directed to systems and methods for rotating a drill string to overcome issues related to static friction during drilling. An embodiment includes a drive system configured to rotate the drill string through variable angular displacements and at variable rotation speeds based on control signals received by the drive system, and a control system configured transmit the control signals to the drive system, wherein the control system is configured to generate the control signals based on pipe characteristics within the drill string and friction values associated with the drill string to establish a rotation pattern of the drive system to approach a desired effective reach of surface torque generated by the drive system on the drill string.
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.
TOP DRIVE MULTI-SERVICE SUPPLY LINE SYSTEM AND METHOD
Present embodiments are directed toward a drilling system that includes a conduit 46 configured to route a pressurized gas to a top drive 24 of a drilling rig 10. The drilling system also includes one or more cables disposed in the conduit. The one or more cables are configured to provide communication, power, or both, to the top drive
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 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
28.
SYSTEMS AND METHODS FOR TUBULAR ENGAGEMENT AND MANIPULATION
SYSTEMS AND METHODS FOR TUBULAR ENGAGEMENT AND MANIPULATION A system for manipulating a tubular (40) about a drilling rig is provided. The system includes a swivel body (50) rotatably coupled with a becket (54). The becket is configured to couple with a traveling block of the drilling rig. The system also includes an engagement feature (26) rotatably coupled with the swivel body. The engagement feature is configured to be actuated to engage the tubular. In addition, the system includes a tilt mechanism (56) configured to be actuated to transition the swivel body and the engagement feature between a tilted orientation and an upright orientation relative to the becket. Further, the system includes an actuator system configured to actuate the tilt mechanism and the engagement feature.
Embodiments of the present disclosure are directed towards a downhole slot cutter. The downhole slot cutter includes a housing of the downhole slot cutter configured to be inserted into a tubular positioned within a wellbore, and a plurality of dies supported by the housing, wherein the plurality of dies is configured to extend radially outward from the housing.
Present embodiments are directed to a top drive system having a top drive, a bogey chassis, wherein the top drive is coupled with the bogey chassis, an upper bushing coupling the bogey chassis to a torque track, and a lower bushing coupling the bogey chassis to the torque track, wherein the upper and lower bushings are configured to translate along the torque track.
Certain embodiments include a system having a first grip configured to couple to a first tubular, a second grip configured to couple to a second tubular, where the first and second tubulars are connected by a threaded connection, and a gear assembly coupling the first and second grips, wherein the gear assembly has a speed ratio greater than 1.
Embodiments of the present disclosure include a system (50) having a clamping (70, 114) mechanism configured to apply a force on a first tool joint (106) and a second tool joint (108), wherein the clamping mechanism is configured to transfer a torque from the first tool joint (106) to the second tool joint (108), and the clamping mechanism (114) is configured to rotate about an axis (72) of the first and second tool joints.
Present embodiments are directed to a gripping device 42, 100, 200, 400 configured to couple with a pipe element 38, 102. A housing 104, 204, 404 of the gripping device is configured to extend over and at least partially around a distal end of the pipe element. Torsional clamp devices 416 are configured to engage an outer circumferential surface of the pipe element with frictional engagement features 84, 112, 212, 800 that extend radially inward from the housing. A sealing mechanism 600 is configured to shift a pipe seal 66 relative to the housing and into engagement with the distal end of the pipe element and to facilitate fluid flow through the gripping device into the pipe element.
Present embodiments are directed to a top drive system 40 comprising a hoisting assembly 50 having an upper link 52, a lower link 54, and a first joint 56 coupling the upper link 52 and the lower link 54. The top drive system 40 also includes a main body 58 coupled to the hoisting assembly 50 by a second joint 60, wherein the hoisting assembly 50 is configured to support the main body 58, and the main body 58 is configured to support a tubular 38. Further, the top drive system 40 includes a frame 62 coupled to the main body 58 and a counter moment system 44 configured to apply a force on the first joint 56 to create a bending moment about the second joint 60.
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 19/08 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods
Present embodiments are directed to a gripping device (42, 100, 200) configured to cooperate with a pipe drive system (40) or top drive to provide a sealed engagement with drillpipe elements (38, 102). The gripping device (42, 100, 200) includes a housing (104, 204) configured to extend over and at least partially around a distal end (44) of the drillpipe element (38, 102). Further, the gripping device (42, 100, 200) includes a seal area positioned along an inner perimeter of the housing (104, 204) such that, when a seal (66, 108, 202) is inserted in the seal area, the seal (66, 108, 202) is arranged to engage with a face (68, 119) of the distal end of the drillpipe element (38, 102) and a face (80, 106, 206) of the gripping device (42, 100, 200). Further, the gripping device (42, 100, 200) includes engagement features (112) configured to extend inwardly from the inner perimeter to facilitate coupling of the gripping device (42, 100, 200) with an outer circumferential area of the drillpipe element (38, 102).
Control lines (12) are secured to a completion string (14) by a wrap (22) wound around the completion string (14) and control lines (12). The control lines (12) are positioned adjacent to the completion string (14) as it is lowered towards a well, and the wrap (22) is wound helically around the lines (12) and string (14) in an open or closed loop manner. The placement and pitch of the wrap (22) may be regulated, such as based upon the rate of advancement of the string (14) into the well. One or multiple wraps (22) may be used, and successive turns of the one or more wraps (22) may overlap or be spaced from one another.
A casing running tool (56) is provided having both axial and circumferentially tapered elements (76). In certain embodiments, the casing running tool (56) comprises cam structures (76) that are circumferentially tapered so as to allow an applied torque to engage and disengage the casing running tool (56) with a casing (22) or liner (14). In embodiments, the circumferential taper of the cam structures (76) allows a mandrel (58) or rollers (90) disposed between the mandrel (58) and cam structures (76) to apply radial force to corresponding shoe structures (78) which in turn engage or disengage the casing (22) or liner (14). The cam structures (76) may also exhibit an axial taper to allow for a self-energized fail-sage operation of the casing running tool (56).
E21B 43/10 - Setting of casings, screens or liners in wells
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
A wedge ring (60) is provided for securing a centralizer (50) or other structure to a tubular element. The wedge ring (60) comprises a first surface comprising a plurality of teeth (64) configured to engage a surface of the tubular element. The wedge ring (60) also comprises a second surface that is threaded (66) to engage a complementary threaded surface (68) of the centralizer (50) or other structure.
Present embodiments are directed to a device for a top drive drilling system (40). The device includes a movable sleeve (68) configured to be disposed around at least a portion of a sub (56). The movable sleeve (68) is configured to be selectively disposed around a tubular (36) by sliding axially along the sub (56). The device also includes a plurality of engagement features (78) extending inwardly from an inner circumference of the movable sleeve (68). When the movable sleeve (68) is disposed around the tubular (36), the plurality of engagement features (78) are configured to engage the tubular (36) when the movable sleeve (68) is rotated in a first direction and to not engage the tubular (36) when the movable sleeve (68) is rotated in a second direction.
Present embodiments are directed to a resonant extractor system (28) configured to use rotational energy provided by a top drive system (24) to apply vertical oscillating motion to attached tubular or drilling equipment. The extractor (28) includes a rotational component (30, 32), an oscillation component (30, 32), and an assembly of engagement features (60, 64), and the rotational component (30, 32) is coupled with the top drive system (24) such that the top drive system (24) may rotate the rotational component (30, 32) about a vertical axis (65). In certain embodiments, the rotational component (32, 30) is a housing (30), the oscillation component (30, 32) is a quill (32), and the engagement features (60, 64) include a cam (64) disposed on a shaft (60). The shaft (60) is coupled to and extends radially into the housing (30), and the cam (64) disposed on the shaft (60), which features an eccentric geometry relative the shaft (60), maintains contact with a lip (52, 100) extending from the quill (32) in the housing (30). As the housing (30) rotates, the eccentric cam (64) rotates, raising and lowering the quill, (32) which is configured to couple with tubular or drilling equipment.
Present embodiments are directed to a top drive torque track system for a drilling rig. The torque track system (20) includes a first elongate track (22, 24, 26, 28, 30, 32, 34) with a male end (62, 88, 108). The male end (62, 88, 108) includes a pin housing (79, 101, 116) and a movable locking pin (100) capable of being biased by a biasing member (66, 120) to extend out of the pin housing (79, 101, 116) and to extend laterally from the male end (62, 88, 108). The torque track system (20) includes a second elongate track (22, 24, 26, 28, 30, 32, 34) having a female end (60, 86, 106) configured to mate with the male end (62, 88, 108). The female end (60, 86, 106) has a locking socket (102, 112) extending laterally within the female end (60, 86, 106). The locking socket (102, 112) is configured to receive the movable locking pin (100). The movable locking pin (100) is configured to engage the locking socket (102, 112) to attach the first elongate track (22, 24, 26, 28, 30, 32, 34) to the second elongate track (22, 24, 26, 28, 30, 32, 34) when the male end (62, 88, 108) of the first elongate track (22, 24, 26, 28, 30, 32, 34) is inserted into the female end (60, 86, 106) of the second elongate track (22, 24, 26, 28, 30, 32, 34).
Present embodiments are directed a stand compensator system (40). The stand compensator system (40) includes gripping device (60) configured to engage a tubular element (38) by coupling about an outer circumference of the tubular element (38). Additionally, the tubular compensator system (40) includes a plurality of resilient roller assemblies (62, 112) positioned proximate an inner perimeter of the gripping device (60), wherein the resilient roller assemblies (62, 112) include rollers (72, 204) arranged to engage with an abutting surface of the tubular element (38). Further, the stand compensator system (40) includes engagement arms (64) coupled with the gripping device (60), wherein the engagement arms (64) are configured to hold the gripping device (60) in position above a tubular elevator (42) and couple between rig bails (44) extending from the tubular elevator (38).
Present embodiments are directed to a tubular catcher system configured to detect a falling tubular (30) through a drilling rig (10) and grip the tubular (30) before it drops into the wellbore. A sensor (44) configured to detect the velocity or acceleration of the tubular (30) activates an actuation mechanism (46) when the velocity or acceleration exceeds a specific threshold, indicating a falling tubular (30). The actuation mechanism (46) forces a gripping mechanism (48) into contact with the tubular (30), catching the tubular (30) and sending energy from the tubular (30) to a hydropneumatic shock absorber (90) coupled to the actuation mechanism (46) and/or the gripping mechanism (48).
E21B 19/16 - Connecting or disconnecting pipe couplings or joints
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 40/00 - Tubing catchers, automatically arresting the fall of oil-well tubing
E21B 41/00 - Equipment or details not covered by groups
Present embodiments are directed to a top drive system (40) equipped with a mounted winch (42) configured to draw tubular or well equipment into alignment with a quill (46) of the top drive system (40). The winch (42) comprises a spool (70) and a flexible line (44) that extends from the spool (70) and through channels (60, 62, 66, 68) in the top drive system (40), exiting through the quill (46). An attachment feature (72) at the distal end of the flexible line (44) couples the flexible line (44) with the tubular or drilling equipment. Once this coupling has been established, the winch (42) may rotate such that the flexible line (44) retracts through the quill (46) of the top drive system (40), drawing the tubular or well equipment into alignment with the quill (46).
A liner top packer is configured to be secured in a liner string, such as in a liner drilling operation. The packer is actuated from within the liner or packer body (22). An actuator assembly includes an inner piston (36), an actuator housing (34), and an outer piston (32). A tubular setting tool (30) is moved upwardly through the inner piston (36), and dogs (52) on the setting tool (30) allow for force to be applied to the inner piston (36), pressurizing fluid and forcing it to the outer piston (32) to compress a pack off element (40). The actuator assembly is removed by upward force applied by a foot of the setting tool on the inner piston (36), the actuator housing (34), or any other component of the actuator assembly.
Present embodiments are directed to coupling a cementation assembly (100) with a hung or set liner string in a well and moving the liner string during a cementation operation. Specifically, for example, a process in accordance with present techniques includes running a cementation assembly into a well on drill pipe and engaging, with a distal end of the cementation assembly, a liner top assembly (44) of a liner string (12) that is positioned downhole in the well, wherein the liner string was previously positioned downhole in the well without being cemented into the well. Further, the process includes latching the cementation assembly with the liner string such that movement of the cementation assembly is translated to the liner string, and flowing cement through the drill pipe and into the liner string while moving the cementation assembly and the liner string.
A casing gripper (100) is stabbed into a casing (300) and energized by a top drive (401), gripping the casing (300). The casing gripper (100) includes a load bearing mandrel (101) that has external threads (114). The casing gripper (100) also includes a nut (113) threaded over the external threads (114), and a wrench (103) having a portion of the upper end (111) of the load bearing mandrel (101) inserted into an opening of the wrench (103). The wrench (103) is configured to prevent rotation of the nut (113) but allow axial movement while the top drive (401) rotates the mandrel (101). The casing gripper (100) includes a grapple (119) coupled to the nut (113) and extending along a portion of the lower end (116) of the load bearing mandrel (101). The grapple (119) moves axially with the nut (113) and is configured to radially expand and engage a casing (300) member.
A packer setting tool sets a liner top packer by mechanical rotation of the running tool and set down weight following cementing of a liner. The packer setting tool includes a tubular release body mounted on an end of the running tool. An annular dog sub circumscribes a portion of the release body. The dog sub is linked to the release body with a shear screw. A thread on an outer surface of the release body engages a thread on an inner surface of the dog sub to define a threaded connection between the dog sub and the release body. When the running tool rotates, the thread on the release body rotates with respect to the thread on the dog sub driving the release body in an axial direction fracturing the shear screw and urges an adapter sleeve against the packer assembly to set the packer assembly.
Embodiments include drilling through a formation (15,16) using a drill bit (20) conveyed by a tubular string (1) having an outer diameter at least 70 percent of the wellbore being drilled. The formation is drilled at a first rate of penetration (ROP) while pumping drilling fluid at a first flow rate. After drilling through the formation, the ROP is reduced to a second ROP, the flow rate is reduced to a second flow rate, and pressure is increased in the wellbore until drilling fluid begins to leak into the formation. While maintaining the increased pressure in the wellbore, the volume of drilling fluid lost to the formation is monitored until the rate at which the drilling fluid loss occurs is reduced. Components of this procedure are repeated until a selected wellbore strength is achieved.
A top drive assembly that includes a gauge for measuring strain in a linkage coupling the top drive to a drilling rig frame. The strain measuring gauge, which can be a strain gauge, is disposed on a pin that pivotingly links members of the linkage coupling. When a motor in the top drive assembly operates to rotate an associated pipe string, the torque generated by the motor can be estimated by monitoring strain measured in the pin.
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
A method of drilling a well and installing a liner includes assembling concentric inner and outer strings of tubulars. A drill bit is located at the lower end of the inner string and a liner with a liner hanger makes up part of the outer string. The inner and outer strings may be rotated in unison to drill the well. A valve is located upstream of a liner hanger control tool used to release and set the liner hanger in the drill string. The valve comprises a ported sleeve that slides relative to a ported housing to meter flow from the interior of the drill string to the annular space. The redirected flow maintains a minimum flow rate in the annular space to prevent cuttings from settling on the control tool. A portion of the valve can further be used with a dart to manipulate downstream equipment.
F16K 17/30 - Excess-flow valves actuated by the difference of pressure between two places in the flow line acting directly on the cutting-off member operating in one direction only spring-loaded
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
F16K 3/26 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with sealing faces shaped as surfaces of solids of revolution with cylindrical valve members with fluid passages in the valve member
F16K 3/34 - Arrangements for modifying the way in which the rate of flow varies during the actuation of the valve
A running tool for well drilling operations is carried by a running string into and out of a wellbore. A collet is carried by the running tool, the collet having fingers with a radially expanded position arranged to latch against a wellbore shoulder in the wellbore. The fingers are resiliently and radially contractible. A shear element is carried by the collet, the shear element preventing the fingers from radially contracting to unlatch the running tool while the shear element is intact. If a selected axial force is applied against the shear element, it shears, freeing the collet fingers to retract. The collet may be part of a tool to set and release a liner hanger from engagement with a string of casing.
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 19/16 - Connecting or disconnecting pipe couplings or joints
E21B 43/10 - Setting of casings, screens or liners in wells
E21B 7/20 - Driving or forcing casings or pipes into boreholes, e.g. sinkingSimultaneously drilling and casing boreholes
A tubing installer runs a string of tubing into a well while strapping a control line to the tubing string. The installer includes a base having a tubular connector extending downward for connection to an upper end of a blowout preventer. Hydraulic cylinders are mounted to and extend upward from the base. A support floor having support slips is mounted to the hydraulic cylinders at a fixed distance above the base. A traveling slip base containing traveling slips is mounted to upper ends of piston rods of the hydraulic cylinders. A pipe lifting assembly is supported by the base for lifting and positioning an additional joint of tubing to be added to the string of tubing. A pipe make-up mechanism is supported by the base for rotating the additional joint into threaded engagement with the string of tubing. A control line supply source for supplies control line to and alongside the string of tubing at a point between the base and the support floor.
A drilling rig having a top drive has a pipe gripper with a mandrel having an upper end for connection to and rotation with a drive string extending downward from the top drive. The pipe gripper has gripping elements that move radially into engagement with a string of pipe. A pull-down mechanism is mounted to the rig and secured to a non-rotating portion of the pipe gripper for exerting a downward force on the mandrel. A sensor is operatively coupled to the top drive to sense weight being supported by the top drive. A controller is linked to the sensor and the pull-down mechanism for controlling the downward force exerted on the mandrel by the pull-down mechanism in response to the weight sensed by the sensor.
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 15/00 - Supports for the drilling machine, e.g. derricks or masts
E21B 19/06 - Elevators, i.e. rod- or tube-gripping devices
A method of cementing a liner in a well includes mounting a valve assembly that is biased in a closed position to a running tool assembly. The running tool assembly has a stinger inserted through the valve assembly, retaining the valve assembly in an open position. The stinger has a cement retainer releasably mounted to it. After lowering the running tool assembly into engagement with the liner string, the operator pumps a cement slurry through the stinger and the valve assembly. The operator then pumps the cement retainer down the liner string into latching engagement with a lower portion of the liner string. Afterward, the operator lifts the stinger from the valve assembly, causing the valve assembly to move to the closed position. The valve assembly blocks upward flow of fluid from the well conduit through the valve assembly in the event of leakage of the cement retainer.
A well drilling tool has a tubular member connected into a casing string that serves as a drill string. A load shoulder is located within the bore of the tubular member. The load shoulder has a torque transferring portion that extends from a lower terminus to an upper terminus. The load shoulder has an axial force transferring portion that faces upward. A bottom hole assembly is lowered through the casing string and lands on the load shoulder. The bottom hole assembly has a mating profile to the load shoulder so that it will be supported by the load shoulder and will receive torque transferred from the load shoulder.
F16D 1/112 - Quick-acting couplings in which the parts are connected by simply bringing them together axially having retaining means rotating with the coupling and acting by interengaging parts, i.e. positive coupling the interengaging parts comprising torque-transmitting surfaces, e.g. bayonet joints
57.
METHOD OF DRILLING AND RUNNING CASING IN LARGE DIAMETER WELLBORE
A well is drilled and casing installed utilizing a casing drilling technique. A bottom hole assembly having a drill bit and a fluid diverter is secured to a string of drill pipe and installed within a casing string. Drilling fluid is pumped down the drill pipe string to cause the drill bit to rotate and drill the well while the fluid diverter is in a drilling mode position. At the total depth for the casing string, the operator moves the fluid diverter to a cementing position and pumps cement down the drill pipe and up the casing string annulus. After cementing, the operator moves the fluid diverter to a packer set position and again pumps drilling fluid down the drill string to set the packer.
A multi-function sub is connected between a top drive of a drilling rig and a casing gripper. The sub has telescoping upper and lower members that rotate with each other. A sleeve is mounted to one of the members. That sleeve is prevented from rotation with the upper and lower members by an anti-rotation device. A piston is located on the other member and reciprocally carried within the sleeve. An external pump is connected to the sleeve for supplying pressurized fluid into the sleeve to act against the piston. This fluid provides compensation for thread makeup when a new joint of casing is being secured to a string of casing.
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
A system for running a string of casing into a well utilizes a casing gripping assembly. The casing gripping assembly connects to a top drive and has radially movable gripping elements. A pair of links have upper ends pivotally connected to the casing gripping assembly. A casing elevator is mounted below the casing gripping assembly to lower ends of the links. A guide is mounted to the links between the elevator and the casing gripping assembly. The guide has a vertically extending central opening that has a lower portion that defines a flared entrance to the opening.
A liner string for a well has a liner hanger assembly at an upper portion of the liner string. A profile sub is located at a bottom portion of the liner string. A bottom hole assembly is latched to the profile sub. The operator lowers the liner string into the well with a drill pipe string and rotates the drill pipe string to rotate the drill bit to deepen the well. At a selected depth, the operator releases the bottom hole assembly from the profile sub and reverse circulates drilling fluid from a liner annulus surrounding the liner string, pumping the bottom hole assembly up the liner string. When the bottom hole assembly reaches the lower end of the drill pipe string, it latches to a catcher tool located at the lower end of the drill pipe string. The operator moves the liner hanger assembly into setting engagement with the casing string, releases the drill pipe string from the liner string, and retrieves the drill pipe string along with the bottom hole assembly.
An underreamer for earth boring operations has a tubular body with a passage extending through it. Arms are pivotally mounted to the body and movable between retracted and extended positions. An actuator mandrel, located within the passage in the body, pushes the arms outward when drilling fluid is pumped downward in the drill string. Ports are located in the sidewall of the body and in the actuator mandrel. The ports align with each other when the mandrel moves to its downstream position. The ports divert a portion of the drilling fluid out to jet it across the cutting elements on the arms. The remaining portion of the drilling fluid passes downward to the drill bit and out nozzles of the drill bit.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutterDrill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
An underreamer earth-boring tool is connected to a bottom hole assembly for casing drilling applications. The underreamer has a tubular body with a longitudinal axis. Arms are pivotally mounted to the body and movable between retracted and extended positions. An array of cutting elements is mounted to each of the arms. Each of the arrays is swept back so that the cutting elements farther from the axis than others rotationally lag the others.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutterDrill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
E21B 10/60 - Drill bits characterised by conduits or nozzles for drilling fluids
63.
METHOD AND APPARATUS FOR RETRIEVING AND INSTALLING A DRILL LOCK ASSEMBLY FOR CASING DRILLING
A method of installing a drilling tool at a lower end of a string of casing suspended in a borehole employs a setting tool run by wireline. The setting tool is latched to a drilling tool connected a drill lock assembly. After landing in a profile sub at the lower end of the casing, fluid pressure is applied to the interior of the string of casing to actuate the setting tool. The setting tool moves to latch the drill lock assembly to the sub so that torque may be transmitted between the profile sub and the drill lock assembly. The setting tool movement also releases the setting tool from the drill lock assembly for retrieval.
A method for securing a wellbore siring device to a wellbore liner tubular employs a swelling elastomer to firictionally grip a gap between the wellbore string device and the liner tubular. The swelling elastomer is positioned between the wellbore string device and the wellbore liner tubular, then activated to cause it to swell to engage the wellbore string device with the wellbore liner tubular. The wellbore string device may be a centralizer, a wear band or a torque ring.
Retrieving a down hole tool at a lower end of a string of casing can be performed with drill pipe during a casing-while-drilling operation. The operator suspends the casing in the well from a drilling rig floor opening. A string drill pipe is lowered into the casing while the casing is suspended for engaging and retrieving the down hole tool. When circulation is desired, the operator secures a circulation tool to an upper end of the drill pipe, then lowers the drill pipe and the circulation tool to close off an upper end of an inner annulus between the drill pipe and the casing. The operator circulates fluid down the circulation tool and the drill pipe and back up an outer annulus surrounding the casing. The connection between the circulation tool and the casing allows the operator to reciprocate the casing.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
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
A stabbing guide connects to a casing collar during makeup. The stabbing guide has a housing with a lower portion with a cylindrical interior and an upper portion with a conical interior. Upper and lower shoulders are located in the cylindrical interior, defining an annular recess between the shoulders. Each of the shoulders has an inner diameter smaller than an outer diameter of the casing collar. The housing is formed in separate segments and secured around the casing collar by a clamp.
A casing-while-drilling bottom hole assembly is releasably connected with a casing string. A retrieval tool is run into the casing string and latched to the bottom hole assembly. Slips are mounted to the retrieval tool, the slips being retracted during running in. Differential pressure moves the retrieval tool and bottom hole assembly upward, and the slips engage the casing string to prevent downward movement if the pressure differential drops too low. A flow passage extends through the retrieval tool and the bottom hole assembly. A check valve in the retrieval tool allows downward flow through the flow passage but prevents upward flow, so that fluid may be circulated through the retrieval tool and bottom hole assembly while suspended with the slips.
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
68.
MONITORING FLOW RATES WHILE RETRIEVING BOTTOM HOLE ASSEMBLY DURING CASING WHILE DRILLING OPERATIONS
A bottom hole assembly in a casing-while-drilling operation is retrieved by reducing the density of the fluid in the casing string above the bottom hole assembly, creating an upward force on the bottom hole assembly. As the bottom hole assembly moves upward in the casing string, fluid is pumped into the upper end of the annulus and displaced fluid flows out of the upper end of the casing string. The flow rate of the fluid flowing into the upper end of the annulus and the flow rate of the displaced fluid flowing out of the casing string are monitored and compared.
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
69.
CIRCULATION SYSTEM FOR RETRIEVAL OF BOTTOM HOLE ASSEMBLY DURING CASING WHILE DRILLING OPERATIONS
During casing-while-drilling, drilling fluid is pumped through a conduit leading to a flow passage a casing string gripper and down the casing string. A bottom hole assembly is mounted at a lower end of the casing string for drilling a wellbore. The bottom hole assembly is retrieved by mounting a circulation sub to the casing string below the casing string gripper, the circulation sub having a lateral outlet. A return flow line is connected from the outlet to the circulation system. The operator flows fluid downward in an annulus of the casing string and back up the casing string, causing the bottom hole assembly to move upward. The fluid flowing back up the casing string is diverted through the outlet in the circulation sub to the circulation system without passing through the flow passage in the casing string gripper.
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
70.
CONTROLLING BACKFLOW PRESSURE DURING RETRIEVAL OF BOTTOM HOLE ASSEMBLY
A bottom hole assembly in a casing-while-dr tiling operation is retrieved by displacing the fluid in the casing string with a less dense fluid than the fluid in the annulus. The bottom hole assembly moves upward in the casing string in response to an upward force due to the different densities of fluid in the casing string and in the annulus. Displaced fluid flows out of the casing string and through a restrictive orifice of a choke. The flow area of the orifice is varied as the bottom hole assembly moves upward to control the rate at which the bottom hole assembly moves upward.
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
71.
INCREMENTAL U-TUBE PROCESS TO RETRIEVE OF BOTTOM HOLE ASSEMBLY DURING CASING WHILE DRILLING OPERATIONS
A bottom hole assembly is retrieved through a casing string by lightening the density of the drilling fluid in the casing string above the bottom hole assembly to a lesser density than the drilling fluid in the casing string annulus. The bottom hole assembly moves upward in the casing string in response to an upward force created by the different densities of fluid. While moving upward, less dense fluid being displaced by the upward movement of the bottom hole assembly flows from the casing string. When the bottom hole assembly stops moving upward, slips suspended it at that intermediate point in the casing string. The operator now lightens the density of the drilling fluid in the casing string below the bottom hole assembly, again creating an upward force on the bottom hole assembly that causes the bottom hole assembly to move upward in the casing string.
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
A slip assembly for gripping pipe during well drilling operations has a housing with a hole for receiving a section of pipe. Pockets in the housing are spaced circumferentially around the hole. Each of the pockets has side walls that face toward each other and are connected to each other by a back wall that has at least one ramp surface. A slip segment is located in each pocket, each slip segment having side edges that engage the side walls of one of the pockets. Each slip segment has a back side with a ramp surface that engages the ramp surface on the back wall of the pocket. Each of the slip segments is movable within its pocket from an upper outward position to a lower inward position in gripping engagement with the pipe.
An installation system for installing a liner in a well includes drilling while simultaneously running the liner. A string of drill pipe with a bottom hole assembly including a drill bit on a lower end is lowered into the liner while the liner is suspended at the rig floor. The bottom hole assembly engages a lower sub of the liner for torque transmission. A running tool secured to the drill pipe engages the upper sub such that the running tool supports the weight of the liner and transmits torque. The drill pipe and liner are rotated to drill deeper into the wellbore. The liner hanger can be set to engage the casing, then released and reset at a different point.
