37 - Construction and mining; installation and repair services
Goods & Services
(1) Electric oil well drilling tools and equipment, namely, pumps and high pressure pumps in the nature of twin pumps for coiled tubing operations, hydraulic fracturing pumps for use with coiled tubing and hydraulic fracturing, pump down pumps for wireline and completion, reverse unit pumps for fishing, and pumps for cementing; hydraulic fracturing equipment in the nature of pumps, slurry blending machines and proppant handlers; hydraulic wet kits powering coiled tubing, snubbing, cementing and wireline units; and wireline units (1) Rental of electric oil well drilling tools and equipment
37 - Construction and mining; installation and repair services
Goods & Services
(1) Power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores; (1) Rental of oil well drilling tools and equipment; rental of power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores;
37 - Construction and mining; installation and repair services
Goods & Services
(1) Electric oil well drilling tools and equipment, namely, pumps and high pressure pumps in the nature of twin pumps for coiled tubing operations, hydraulic fracturing pumps for use with coiled tubing and hydraulic fracturing, pump down pumps for wireline and completion, reverse unit pumps for fishing, and pumps for cementing; hydraulic fracturing equipment in the nature of pumps, slurry blending machines and proppant handlers; hydraulic wet kits powering coiled tubing, snubbing, cementing and wireline units; and wireline units; (1) Rental of electric oil well drilling tools and equipment;
37 - Construction and mining; installation and repair services
Goods & Services
(1) Power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores; (1) Rental of oil well drilling tools and equipment; rental of power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores;
37 - Construction and mining; installation and repair services
Goods & Services
(1) Power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores; (1) Rental of oil well drilling tools and equipment; rental of power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores;
37 - Construction and mining; installation and repair services
Goods & Services
(1) Power operated thru tubing drilling motors; (1) Rental of oil well drilling tools and equipment; rental of power operated thru tubing drilling motors;
37 - Construction and mining; installation and repair services
Goods & Services
(1) Power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores; (1) Rental of oil well drilling tools and equipment; rental of power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores;
37 - Construction and mining; installation and repair services
Goods & Services
(1) Electric oil well drilling tools and equipment, namely, pumps and high pressure pumps in the nature of twin pumps for coiled tubing operations, hydraulic fracturing pumps for use with coiled tubing and hydraulic fracturing, pump down pumps for wireline and completion, reverse unit pumps for fishing, and pumps for cementing; hydraulic fracturing equipment in the nature of pumps, slurry blending machines and proppant handlers; hydraulic wet kits powering coiled tubing, snubbing, cementing and wireline units; and wireline units; (1) Rental of electric oil well drilling tools and equipment;
A downhole tool comprises a tool housing defining a flow passage therethrough from a first to a second end thereof. A poppet is axially movable on a poppet mandrel positioned in the tool housing. The poppet mandrel has at least one outlet port defined therein. A pilot valve is rotatable about the poppet mandrel. Rotation of the pilot valve opens and closes the at least one outlet port in the poppet mandrel to permit and block flow therethrough, and wherein the opening and closing of the at least one outlet port moves the poppet axially on the poppet mandrel.
A downhole tool configured for inclusion in a drill string, typically as part of a bottom hole assembly. The downhole tool configured to improve passage of the drill string through a borehole. Additionally, the downhole tool is suitable for use in a method for improving passage of a drill string through a borehole.
A downhole tool configured for inclusion in a drill string, typically as part of a bottom hole assembly. The downhole tool configured to improve passage of the drill string through a borehole. Additionally, the downhole tool is suitable for use in a method for improving passage of a drill string through a borehole.
A downhole tool comprises a tool housing defining a flow passage therethrough from a first to a second end thereof. A poppet is axially movable on a poppet mandrel positioned in the tool housing. The poppet mandrel has at least one outlet port defined therein. A pilot valve is rotatable about the poppet mandrel. Rotation of the pilot valve opens and closes the at least one outlet port in the poppet mandrel to permit and block flow therethrough, and wherein the opening and closing of the at least one outlet port moves the poppet axially on the poppet mandrel.
A seal and clamping system for a wellhead assembly having a housing with a first end configured to seal to the outer adapter surface above an upper outward-projecting shoulder on the wellhead assembly, a second end configured to seal to the tubing head below a lower outward-projecting shoulder, and a clamping system configured to hold the housing in position about the wellhead assembly so as to ensure sealing contact at the upper end and lower end with the wellhead assembly.
F16B 2/08 - Clamps, i.e. with gripping action effected by positive means other than the inherent resistance to deformation of the material of the fastening external, i.e. with contracting action using bands
15.
Apparatus and method for removing debris from a well bore
A tool for cleaning debris from a wellbore comprises a rotational portion and a stationary portion. The rotational portion is configured to be coupled to a workstring disposed in the wellbore such that rotation of the workstring rotates the rotational portion. The stationary portion at least partially surrounds the rotational portion. The stationary portion is configured to remain stationary when the rotational portion and the workstring are rotated. The rotational portion and the stationary portion are shaped and configured such that when the workstring is at least partially disposed in well fluid present in the wellbore, rotation of the rotational portion causes the movement of well fluid such that well fluid flows in the workstring, thereby carrying debris from the wellbore in to the workstring.
37 - Construction and mining; installation and repair services
Goods & Services
Oil well drilling tools and equipment, namely, power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores Rental of oil well drilling tools and equipment; rental of oil well drilling tools and equipment, namely, power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores
37 - Construction and mining; installation and repair services
Goods & Services
Oil well drilling tools and equipment, namely, power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores Rental of oil well drilling tools and equipment; rental of oil well drilling tools and equipment, namely, power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores
37 - Construction and mining; installation and repair services
Goods & Services
Oil well drilling tools and equipment, namely, power operated thru-tubing drilling motors Rental of oil well drilling tools and equipment, namely, power operated thru-tubing drilling motors
37 - Construction and mining; installation and repair services
Goods & Services
Oil well drilling tools and equipment, namely, power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores Rental of oil well drilling tools and equipment; rental of oil well drilling tools and equipment, namely, power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores
37 - Construction and mining; installation and repair services
Goods & Services
Oil well drilling tools and equipment, namely, power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores Rental of oil well drilling tools and equipment; rental of oil well drilling tools and equipment, namely, power operated extended reach tools for drilling, milling, cleaning, and fishing operations in subterranean wellbores
Electric oil well drilling tools and equipment, namely, pumps and high pressure pumps in the nature of twin pumps for coiled tubing operations, pumps for use with coiled tubing, pump-down pumps for wireline and completion, reverse unit pumps for fishing, pumps for cementing, slurry blending machines, wireline units, and hydraulic wet kits consisting essentially of powering coiled tubing, snubbing, cementing and wireline units
Electric oil well drilling tools and equipment, namely, pumps and high pressure pumps in the nature of twin pumps for coiled tubing operations, pumps for use with coiled tubing, pump-down pumps for wireline and completion, reverse unit pumps for fishing, pumps for cementing, slurry blending machines, wireline units, and hydraulic wet kits consisting essentially of powering coiled tubing, snubbing, cementing and wireline units
Electric oil well drilling tools and equipment, namely, pumps and high pressure pumps in the nature of twin pumps for coiled tubing operations, pumps for use with coiled tubing, pump-down pumps for wireline and completion, reverse unit pumps for fishing, pumps for cementing, slurry blending machines, wireline units, and hydraulic wet kits consisting essentially of powering coiled tubing, snubbing, cementing and wireline units
A plunger tool and method relating thereto is designed to remove and insert plungers of a reciprocating pump such as during maintenance and other disassembly operations. The tool has a guide which receives and supports the plunger after removal from, and before reinsertion into, the pump. The tool also has a rack and pinion actuator for moving the plunger.
A tool for running a casing string assembly into a wellbore includes a degradable plug assembly that temporarily isolates light fluid trapped in a lower portion of the casing string from heavier fluid in the upper portion of the casing string, thereby reducing the horizontal weight of the casing string by an amount sufficient to overcome a drag force. After the casing string is landed at a final location in the wellbore, fluid is introduced to the degradable plug assembly to degrade the plug and clear the axial passageway of the casing string so that tools or other equipment can pass therethrough.
E21B 29/00 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground
A plunger tool and method relating thereto is designed to remove and insert plungers of a reciprocating pump such as during maintenance and other disassembly operations. The tool has a guide which receives and supports the plunger after removal from, and before reinsertion into, the pump. The tool also has a rack and pinion actuator for moving the plunger.
A gate-valve and/or hot-tap drilling system uses a secondary pack-off or sealing element which can be engaged when the primary sealing element develops a leak. Generally, the secondary sealing element is configured to have an engaged position in which a fluid tight seal is formed such that the secondary sealing element engages the bore wall in a pressure-containing housing and drill rod extending through the bore defined by the bore wall. The fluid tight seal prevents fluid flow in the annulus, if the primary seal develops a leak. When the primary seal is working normally—no fluid leak—the secondary sealing element is in a disengaged position where a fluid tight seal is not formed with the bore wall and drill rod.
09 - Scientific and electric apparatus and instruments
Goods & Services
Sensors for measuring RPM, shock, vibration and temperature, not for medical use; Sensors for measuring RPM, shock, vibration and temperature used on drill and tool strings in the nature of a column of drill pipe for oil and gas exploration and production operations; Electrical and electronic instruments for measuring and monitoring RPM, shock, vibration and temperature
A plunger tool and method relating thereto is designed to remove and insert plungers of a reciprocating pump such as during maintenance and other disassembly operations. The tool has a guide which receives and supports the plunger after removal from, and before reinsertion into, the pump. The tool also has a rack and pinion actuator for moving the plunger.
A tool for cleaning debris from a wellbore comprises a rotational portion and a stationary portion. The rotational portion is configured to be coupled to a workstring disposed in the wellbore such that rotation of the workstring rotates the rotational portion. The stationary portion at least partially surrounds the rotational portion. The stationary portion is configured to remain stationary when the rotational portion and the workstring are rotated. The rotational portion and the stationary portion are shaped and configured such that, when the workstring is at least partially disposed in well fluid present in the wellbore, rotation of the rotational portion causes movement of well fluid such that well fluid flows into the workstring, thereby carrying debris from the wellbore into the workstring.
A tool for cleaning debris from a wellbore comprises a rotational portion and a stationary portion. The rotational portion is configured to be coupled to a workstring disposed in the wellbore such that rotation of the workstring rotates the rotational portion. The stationary portion at least partially surrounds the rotational portion. The stationary portion is configured to remain stationary when the rotational portion and the workstring are rotated. The rotational portion and the stationary portion are shaped and configured such that, when the workstring is at least partially disposed in well fluid present in the wellbore, rotation of the rotational portion causes movement of well fluid such that well fluid flows down into the workstring, thereby carrying debris from the wellbore into the workstring.
E21B 27/04 - Containers for collecting or depositing substances in boreholes or wells, e.g. bailers for collecting mud or sandDrill bits with means for collecting substances, e.g. valve drill bits where the collecting or depositing means include helical conveying means
E21B 37/00 - Methods or apparatus for cleaning boreholes or wells
34.
Lateral propulsion apparatus and method for use in a wellbore
A lateral propulsion apparatus positioned onto a drillstring comprising a tubular housing, venturi nozzles, an impeller, and flow ports. The apparatus utilizes both the venturi effect as well as rotational forces to cause wellbore fluid to travel from an area of high pressure near a lower end toward an area of lower pressure near an upper end urging the apparatus further into a non-vertical wellbore.
E21B 41/00 - Equipment or details not covered by groups
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 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
35.
LATERAL PROPULSION APPARATUS AND METHOD FOR USE IN A WELLBORE
A lateral propulsion apparatus positioned onto a drillstring comprising a tubular housing, venturi nozzles, an impeller, and flow ports. The apparatus utilizes both the venturi effect as well as rotational forces to cause wellbore fluid to travel from an area of high pressure near a lower end toward an area of lower pressure near an upper end urging the apparatus further into a non-vertical wellbore.
A pressure actuated jarring apparatus includes a tubular housing, a piston, a spring element, and a seat. The tubular housing has a passage therethrough extending from an upper end to a lower end. The piston is disposed within the central bore and is movable axially between an inactivated state and an activated state. The spring element is configured to store energy to drive the piston from the activated state. The seat is coupled to the piston such that when a plug is seated in an orifice of the seat fluid is prevented from flowing through the orifice. The jarring device is fired by increasing pressure in the passage until the plug is forced through the seat, thereby releasing the energy in the spring element and driving the piston from the activated state so that it impacts an abutment and generates a jarring force.
A pressure activated cyclical valve assembly includes a first sub, a second sub, a piston, and a biasing member. The first sub has a first passageway therethrough. The second sub is coupled to the first sub and has a second passageway therethrough. The piston is positioned within the second passageway and is shiftable between a deactivated position in which a bypass port is closed and an activated position in which the bypass port is open. The piston has a piston orifice and the first passageway is in fluid communication with the second passageway through the piston orifice. The biasing member exerts a force against the piston to maintain the piston in the deactivated position. The piston orifice is sized to restrict the flow of fluid therethrough such that the piston can be shifted between the deactivated and activated positions by changing flowrate of fluid in the first passageway.
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
F16K 17/04 - Safety valvesEqualising valves opening on surplus pressure on one sideSafety valvesEqualising valves closing on insufficient pressure on one side spring-loaded
38.
APPARATUS AND METHOD FOR RUNNING CASING IN A WELLBORE
A float collar tool for running a casing string assembly into a wellbore includes a non-fragmenting rupture disc that temporarily isolates light fluid trapped in a lower portion of the casing string from heavier fluid in the upper portion of the casing string, thereby reducing the horizontal weight of the casing string by an amount sufficient to overcome a drag force. After the casing string is landed at a final location in the wellbore, the rupture disc is burst by increasing fluid pressure in the upper portion of the casing string. The increased pressure activates a piston that then moves the burst rupture disc into a protective region of the tool so that the inside diameter of the casing string is substantially restored.
A float collar tool for running a casing string assembly into a wellbore includes a non-fragmenting rupture disc that temporarily isolates light fluid trapped in a lower portion of the casing string from heavier fluid in the upper portion of the casing string, thereby reducing the horizontal weight of the casing string by an amount sufficient to overcome a drag force. After the casing string is landed at a final location in the wellbore, the rupture disc is burst by increasing fluid pressure in the upper portion of the casing string. The increased pressure activates a piston that then moves the burst rupture disc into a protective region of the tool so that the inside diameter of the casing string is substantially restored.
E21B 43/10 - Setting of casings, screens or liners in wells
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
40.
Rotor catch apparatus for downhole motor and method of use
A rotor catch assembly for connection in a workstring in a wellbore is provided. The rotor catch assembly is connected to a downhole motor assembly that includes a rotor that is driven by a fluid. In the normal operating state of the rotor catch assembly, fluid flows through the catch assembly and causes the rotor to rotate. In this state, the catch assembly generates pressure pulses in the fluid in the workstring to facilitate advancement of the workstring in the wellbore. In the event of a failure of a mechanical connection in the motor assembly, the rotor catch assembly shifts to a catch-activated state in which the motor assembly is disabled.
E21B 47/09 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
E21B 31/00 - Fishing for or freeing objects in boreholes or wells
A rotor catch assembly for connection in a workstring in a wellbore is provided. The rotor catch assembly is connected to a downhole motor assembly that includes a rotor that is driven by a fluid. In the normal operating state of the rotor catch assembly, fluid flows through the catch assembly and causes the rotor to rotate. In this state, the catch assembly generates pressure pulses in the fluid in the workstring to facilitate advancement of the workstring in the wellbore. In the event of a failure of a mechanical connection in the motor assembly, the rotor catch assembly shifts to a catch-activated state in which the motor assembly is disabled.
An apparatus for at least partially sealing an annulus of a wellbore comprises a hollow mandrel pipe adapted to attach to a tubing string, and a cylindrical cage surrounding and attached to an exterior length of the mandrel pipe, the cylindrical cage having a plurality of generally lengthwise tortuous path apertures generally parallel with one another between the two open ends of the mandrel pipe, the plurality of generally lengthwise tortuous path apertures defining a plurality of bow springs therebetween, the plurality of bow springs bowed outward from the mandrel pipe.
An apparatus for at least partially sealing an annulus of a wellbore comprises a hollow mandrel pipe adapted to attach to a tubing string, and a cylindrical cage surrounding and attached to an exterior length of the mandrel pipe, the cylindrical cage having a plurality of generally lengthwise tortuous path apertures generally parallel with one another between the two open ends of the mandrel pipe, the plurality of generally lengthwise tortuous path apertures defining a plurality of bow springs therebetween, the plurality of bow springs bowed outward from the mandrel pipe.
An apparatus for at least partially sealing an annulus of a wellbore comprises a hollow mandrel pipe adapted to attach to a tubing string, and a cylindrical cage surrounding and attached to an exterior length of the mandrel pipe, the cylindrical cage having a plurality of generally lengthwise tortuous path apertures generally parallel with one another between the two open ends of the mandrel pipe, the plurality of generally lengthwise tortuous path apertures defining a plurality of bow springs therebetween, the plurality of bow springs bowed outward from the mandrel pipe.
An apparatus for creating vibrations in a pipe string is disclosed. The device comprises a fluid pump which pumps fluid within a first fluid bore and is connected to the pipe string. A hydraulic pump pumps fluid within a second fluid bore and a movable plunger disposed between the first fluid bore and the second fluid bore intermittently opens and closes access to a tank based on changes to a pressure of the fluid pump. The tank for collecting at least a portion of the fluid is connected to the apparatus via the first fluid bore, and the movement of the plunger is configured to generate vibrations within the pipe string by altering the amount of fluid allowed to flow to the tank.
E21B 28/00 - Vibration generating arrangements for boreholes or wells, e.g. for stimulating production
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
An apparatus for creating vibrations in a pipe string is disclosed. The device comprises a fluid pump which pumps fluid within a first fluid bore and is connected to the pipe string. A hydraulic pump pumps fluid within a second fluid bore and a movable plunger disposed between the first fluid bore and the second fluid bore intermittently opens and closes access to a tank based on changes to a pressure of the fluid pump. The tank for collecting at least a portion of the fluid is connected to the apparatus via the first fluid bore, and the movement of the plunger is configured to generate vibrations within the pipe string by altering the amount of fluid allowed to flow to the tank.
An apparatus for creating vibrations in a pipe string is disclosed. The device comprises a fluid pump which pumps fluid within a first fluid bore and is connected to the pipe string. A hydraulic pump pumps fluid within a second fluid bore and a movable plunger disposed between the first fluid bore and the second fluid bore intermittently opens and closes access to a tank based on changes to a pressure of the fluid pump. The tank for collecting at least a portion of the fluid is connected to the apparatus via the first fluid bore, and the movement of the plunger is configured to generate vibrations within the pipe string by altering the amount of fluid allowed to flow to the tank.
F04B 49/18 - Control of, or safety measures for, machines, pumps, or pumping installations, not otherwise provided for in, or of interest apart from, groups by changing the effective cross-section of the working surface of the piston
E21B 28/00 - Vibration generating arrangements for boreholes or wells, e.g. for stimulating production
A method for assembly of a device is disclosed. The device comprises a quick connect apparatus that includes a first member having a male locking profile on an outer surface and a second member having a female locking profile on an inner surface. The method includes stabbing the second member onto the first member to fully seat the first member within the second member, rotating the second member relative to the first member to lock the male locking profile to the female locking profile, and engaging a second locking mechanism to restrict further rotation of the second member relative to the first member.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 17/04 - CouplingsJoints between rod and bit, or between rod and rod
E21B 17/043 - CouplingsJoints between rod and bit, or between rod and rod threaded with locking means
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
E21B 23/03 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets
F16L 25/06 - Construction or details of pipe joints not provided for in, or of interest apart from, groups comprising radial locking means
50.
DRIVE SHAFT ASSEMBLY FOR DOWNHOLE MUD MOTOR CONFIGURED FOR DIRECTIONAL DRILLING
A driveshaft assembly comprises a cylindrical upper member, with one end of the upper member being connected to the rotor and an other end of the upper member having a plurality of torque transmitting profiles. An elongated central member has two ends, with each end having a plurality of torque transmitting profiles. A seat is retained within a central bore of the upper member, the seat having a curved end. A catch is retained within the central member, the catch having a curved end. The upper member transfers torque from the rotor to the central member via the torque transmitting profiles of the upper member and the torque transmitting profiles of the central member, and the curved end of the seat contacts the curved end of the catch while maintaining a gap between the other end of the upper member and the adjacent end of the central member.
A driveshaft assembly comprises a cylindrical upper member, with one end of the upper member being connected to the rotor and an other end of the upper member having a plurality of torque transmitting profiles. An elongated central member has two ends, with each end having a plurality of torque transmitting profiles. A seat is retained within a central bore of the upper member, the seat having a curved end. A catch is retained within the central member, the catch having a curved end. The upper member transfers torque from the rotor to the central member via the torque transmitting profiles of the upper member and the torque transmitting profiles of the central member, and the curved end of the seat contacts the curved end of the catch while maintaining a gap between the other end of the upper member and the adjacent end of the central member.
A driveshaft assembly comprises a cylindrical upper member, with one end of the upper member being connected to the rotor and an other end of the upper member having a plurality of torque transmitting profiles. An elongated central member has two ends, with each end having a plurality of torque transmitting profiles. A seat is retained within a central bore of the upper member, the seat having a curved end. A catch is retained within the central member, the catch having a curved end. The upper member transfers torque from the rotor to the central member via the torque transmitting profiles of the upper member and the torque transmitting profiles of the central member, and the curved end of the seat contacts the curved end of the catch while maintaining a gap between the other end of the upper member and the adjacent end of the central member.
E21B 4/00 - Drives for drilling, used in the borehole
F16D 3/18 - Universal joints in which flexibility is produced by means of pivots or sliding or rolling connecting parts the coupling parts having slidably-interengaging teeth
A vibrator apparatus to be positioned onto a pipe string is disclosed. The apparatus is comprised of a tubular housing, a tubular stator having a radial fluid opening, and a rotating rotor shaft with a longitudinally extending fluid bore and at least one radially extending fluid passage that intermittently aligns with the stator fluid opening. A rotation generator is provided to rotate the rotor shaft in response to fluid flow. Fluid flow through the fluid bore of the rotor shaft is discharged from the radially extending fluid passage of the rotor as it rotates in response to fluid flow and is intermittently interrupted by the stator as the rotor is rotated past the radial fluid opening in the stator thereby creating pulses in the fluid column and vibrating the pipe string.
A mechanically activated bypass valve apparatus for allowing fluid being pumped through the pipe or coiled tubing string to be bypassed around a tool string and into the wellbore. Activation of the bypass valve is accomplished by applying weight-on-bit to the apparatus to shear a set of shear screws, allowing the mandrel to move axially relative to the tubular housing. Lowering the pipe string and setting down weigh on bit misaligns fluid bypass ports in the mandrel and housing, thus forcing fluid to continue to flow through the bore of the tool and to the toolstring below the bypass tool. Picking up on the pipe string aligns corresponding ports in the mandrel and housing and allows fluid to flow from the bore of the tool to the wellbore annulus, thus bypassing other tools downhole of the apparatus.
A mechanically activated bypass valve apparatus for allowing fluid being pumped through the pipe or coiled tubing string to be bypassed around a tool string and into the wellbore. Activation of the bypass valve is accomplished by applying weight-on-bit to the apparatus to shear a set of shear screws, allowing the mandrel to move axially relative to the tubular housing. Lowering the pipe string and setting down weigh on bit misaligns fluid bypass ports in the mandrel and housing, thus forcing fluid to continue to flow through the bore of the tool and to the toolstring below the bypass tool. Picking up on the pipe string aligns corresponding ports in the mandrel and housing and allows fluid to flow from the bore of the tool to the wellbore annulus, thus bypassing other tools downhole of the apparatus.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
57.
Pressure activated cyclical valve apparatus and method
A bypass tool has a piston movable within the bore of a central housing. A control slot on an exterior wall of the piston engages a slot pin in the housing. Longitudinal movement of the piston is downward, in response to fluid pressure exerted on a ball seated on a ball seat on the piston; and spring biased upward. The control slot and slot pin rotate the piston as it moves longitudinally between a first, upper position in which bypass ports in the housing are closed, and a second, lower position in which the bypass ports are open. An intermediate longitudinal position has the ports closed, and permits pressuring up on a ball to force it through the ball seat and reset the tool in the flow through position. The ball and/or ball seat may be of resilient material to permit passage of the ball through the seat.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 34/00 - Valve arrangements for boreholes or wells
An apparatus for dampening vibrations in a drill string has a tubular housing with an upper sub connected to a first end, having a threaded connection for engagement with the pipe or drillstring. A piston is positioned in the bore of the tubular housing and longitudinally movable in the bore; the dimensions of the piston and bore permit limited fluid flow around the piston. Connected to the piston and extending out of the second end of the housing is a bottom sub. Mating and engaging profiles in the tubular housing and lower sub allow longitudinal movement between them, but no relative rotation. A spring member, which may be a mechanical spring, an elastomeric member, a compressed gas, or some combination thereof, biases the piston and lower sub out of the tubular housing.
A friction reduction apparatus (FRA) positioned onto a pipe string comprises a tubular housing, upper and lower mandrels having variously configured fluid flow passages and ports, a valve and a shifter. Fluid travelling through the apparatus causes the valve and shifter to reciprocate, repeatedly opening and closing flow passages. Each of these cycles creates a pulse in the fluid column creating vibrations that reduce friction in the pipe string. The FRA can be used in conjunction with a ball or dart activated tool positioned downhole from the FRA.
A friction reduction apparatus (FRA) positioned onto a pipe string comprises a tubular housing, upper and lower mandrels having variously configured fluid flow passages and ports, a valve and a shifter. Fluid travelling through the apparatus causes the valve and shifter to reciprocate, repeatedly opening and closing flow passages. Each of these cycles creates a pulse in the fluid column creating vibrations that reduce friction in the pipe string. The FRA can be used in conjunction with a ball or dart activated tool positioned downhole from the FRA.
A friction reduction apparatus (FRA) positioned onto a pipe string comprises a tubular housing, upper and lower mandrels having variously configured fluid flow passages and ports, a valve and a shifter. Fluid travelling through the apparatus causes the valve and shifter to reciprocate, repeatedly opening and closing flow passages. Each of these cycles creates a pulse in the fluid column creating vibrations that reduce friction in the pipe string. The FRA can be used in conjunction with a ball or dart activated tool positioned downhole from the FRA.
37 - Construction and mining; installation and repair services
Goods & Services
Distributorships in the field of aircraft and structural and
replacement parts therefor; supply chain and inventory
management services; employment staffing in the field of
expert operators for the oil and gas industry. Rental of oil well drilling tools and equipment.
A downhole separation apparatus for releasing a pipe string from a bottom hole assembly is disclosed. The apparatus has a tubular collet body, a tubular bottom sub, and a piston collet positioned within the collet body. The collet piston has a plurality of collet fingers threadedly engaging an internal profile of the bottom sub. Separation is accomplished by pumping a circulation ball through the pipe string until it lands on a ball seat inside the collet piston. Increasing fluid pressure then shifts the piston collet axially downward within the collet body thereby causing the collet fingers to collapse to disengage the bottom hole assembly from the pipe string.
E21B 17/046 - CouplingsJoints between rod and bit, or between rod and rod with ribs, pins, or jaws, and complementary grooves or the like, e.g. bayonet catches
E21B 31/00 - Fishing for or freeing objects in boreholes or wells
37 - Construction and mining; installation and repair services
Goods & Services
Distributorships in the field of aircraft and structural and
replacement parts therefor; supply chain and inventory
management services; employment staffing in the field of
expert operators for the oil and gas industry. Rental of oil well drilling tools and equipment.
65.
IMPROVED BEARING ASSEMBLY FOR DOWNHOLE MOTOR HAVING FIRST AND SECOND THRUST BEARINGS
A downhole motor for drilling and servicing of wells has an elongated outer housing and an elongated mandrel rotatably disposed within the housing. A primary thrust bearing is disposed between the lower end of the housing and the mandrel, and transfers axial loads downward from the housing to the mandrel, and thence to the drill bit or other tool mounted on the lowermost end of the mandrel. A secondary thrust bearing is disposed between the housing and the mandrel, and transfers forces from the mandrel to the housing. The placement of the primary thrust bearing permits it to extend radially to the outer diameter of the housing. One preferred embodiment of the primary thrust bearing comprises bearing surfaces of polycrystalline diamond compact ("PDC") material.
E21B 4/00 - Drives for drilling, used in the borehole
F16C 19/02 - Bearings with rolling contact, for exclusively rotary movement with bearing balls essentially of the same size in one or more circular rows
F16C 29/00 - Bearings for parts moving only linearly
F16C 31/00 - Bearings for parts which both rotate and move linearly
A downhole motor for drilling and servicing of wells has an elongated outer housing and an elongated mandrel rotatably disposed within the housing. A primary thrust bearing is disposed between the lower end of the housing and the mandrel, and transfers axial loads downward from the housing to the mandrel, and thence to the drill bit or other tool mounted on the lowermost end of the mandrel. The placement of the primary thrust bearing permits it to extend radially to the outer diameter of the housing. One preferred embodiment of the primary thrust bearing comprises bearing surfaces of polycrystalline diamond compact ("PDC") material.
A hydraulic percussive apparatus is disclosed for generating vibrating forces to a pipe string. The apparatus is attached to the pipe string a central bore through which fluid may be introduced into the apparatus. The apparatus has a tubular housing, an anvil surface with an irregularly profiled surface, and a rotor with an irregularly profiled hammer surface that is urged to move axially toward and away from the anvil surface. The rotor has a longitudinally extending fluid bore and a tangentially oriented fluid port in communication with the longitudinal fluid bore of the rotor. Fluid entering the rotor's fluid bore and exiting the rotor's tangentially oriented fluid port rotates the rotor, and thus the irregularly profiled hammer surface on the irregularly profiled anvil surface, moving the hammer surface toward and away from the anvil producing intermittent impact forces.
A downhole motor for drilling and servicing of wells has an elongated outer housing and an elongated mandrel rotatably disposed within the housing. A primary thrust bearing is disposed between the lower end of the housing and the mandrel, and transfers axial loads downward from the housing to the mandrel, and then to the drill bit or other tool mounted on the lowermost end of the mandrel. The placement of the primary thrust bearing permits it to extend radially to the outer diameter of the housing. One preferred embodiment of the primary thrust bearing comprises bearing surfaces of polycrystalline diamond compact (“PDC”) material.
A downhole motor for drilling and servicing of wells has an elongated outer housing and an elongated mandrel rotatably disposed within the housing. A primary thrust bearing is disposed between the lower end of the housing and the mandrel, and transfers axial loads downward from the housing to the mandrel, and then to the drill bit or other tool mounted on the lowermost end of the mandrel. The placement of the primary thrust bearing permits it to extend radially to the outer diameter of the housing. One preferred embodiment of the primary thrust bearing comprises bearing surfaces of polycrystalline diamond compact (“PDC”) material.
