Abstract: A completion system and method adapted for use in wells having long lateral boreholes includes a mast assembly, a pipe handling mechanism, a pipe arm, a pipe tub, a pump/pit combination skid, a rig carrier, and a control system. The mast assembly can extend in a generally vertical direction, e.g., perpendicular to the rig carrier and/or the earth's surface, such that the rig can be placed directly adjacent to a wellbore, and the top drive or a similar drive system can be engaged with and move along the mast while remaining above the wellbore. The top drive can be engaged with a support fixture that resists torque and rotation during operation. The support fixture can in turn be engaged with the mast to transfer torque forces to the mast while being vertically movable along the mast to enable positioning of the top drive.

Abstract: Methods and apparatus for diverting fluids either into or from a well are described. Some embodiments include a diverter conduit that is located in a bore of a tree. The invention relates especially but not exclusively to a diverter assembly connected to a wing branch of a tree. Some embodiments allow diversion of fluids out of a tree to a subsea processing apparatus followed by the return of at least some of these fluids to the tree for recovery. Alternative embodiments provide only one flowpath and do not include the return of any fluids to the tree. Some embodiments can be retro-fitted to existing trees, which can allow the performance of a new function without having to replacing the tree. Multiple diverter assembly embodiments are also described.

Abstract: A method of testing a barrier in a wellbore that includes isolating a volume in the wellbore between an isolation device connected with an apparatus and the barrier, and pressure testing the barrier using the apparatus to adjust the pressure in the volume.

Abstract: Disclosed is an improved tension member or slickline used in wellbore intervention operations. One exemplary tension member includes a first portion comprising a metallic material and having a distal end, a second portion comprising a non-metallic material and having a proximal end, and a joint coupling the proximal end of the second portion to the distal end of the first portion.

Abstract: Disclosed is a cost-effective remedy to loss of well control caused by a defective string section upstream of the BHA, and more cost-effective inspection, maintenance, repair and replacement of any tools placed upstream of the BHA. The solution is to deploy one or more tools along the length of the string, either: (i) each tool below a profile nipple, and where each tool is upstream from an adjacent downhole safety valve (“DSV”); or (ii) one or more Flapper-tool-DSV combinations each below a profile nipple, and where the tool is positioned between each Flapper and DSV in the combination. If desired, the valving system described may be deployed along the string without a tool, to allow section-by-section inspection, maintenance, repair and replacement of string sections.

Abstract: In accordance with embodiments of the present disclosure, a perforating system for perforating a subterranean formation includes a carrier gun body having a cylindrical sleeve. The perforating system also includes a charge holder disposed in the cylindrical sleeve and a plurality of charges disposed on the charge holder. The charge holder is dissolvable in at least one wellbore fluid delivered through the carrier gun body after detonation of the charges. The charges may also be dissolvable during or after detonation. In some embodiments, the carrier gun body is dissolvable wellbore fluid delivered through the carrier gun body. By including dissolvable parts, the disclosed perforating gun yields relatively lower amounts of debris in the wellbore after detonation. In addition, the dissolving portions of the perforating gun allow the remaining portions of the gun to be used to perform wellbore operations downhole without pulling the perforating gun.

Abstract: A drill rod clamping system for securing a drill rod in a selected position. The drill rod clamping system has a hollow spindle with an upper portion that defines axial slots and a base portion that defines at least one radial opening. A plurality of jaws are moveable radially inwardly to a drill rod gripping position and radially outwardly to a drill rod releasing position. Each jaw is received within a respective axial slot of the hollow spindle. An actuator moves the plurality of jaws between the drill rod gripping position and the drill rod releasing position. A compressed gas spring assembly exerts force on the actuator to close the jaws. A hydraulic operator exerts force on the actuator to overcome the force of the compressed gas spring assembly to open the jaws. The radial openings of the base portion of the spindle permit flushing of material flowing within the spindle.

Abstract: A self-adjusting lockdown assembly for engaging and/or preloading a tubular hanger to an interior of a wellhead housing. The lockdown assembly includes a support sleeve, a body received in the support sleeve, an elevator ring coaxially engaged with the support sleeve, a lock ring engaged with the elevator ring, and an actuator sleeve configured to move axially between the body and the elevator ring so as to adjust the position of the lock ring.

Abstract: In some example embodiments, a system includes a drill string having a drill bit. The drill string extends through at least part of a well bore. The system also includes a first vibrational sensor, positioned on the drill bit to measure, at a first location on the drill string, an amplitude of one or more of an axial vibration and a lateral vibration. The system also includes a second vibrational sensor, positioned above the drill bit and on the drill string. The second vibration sensor is to measure, at a second location on the drill string, one or more of an axial vibration and a lateral vibration. The system includes a processor unit to determine a type of vibration based on a comparison of the amplitude at the first location to the amplitude at the second location, wherein the type of vibration is at least one of bit whirl of the drill bit and a while of a bottom hole assembly that is part of the drill string.

Abstract: A method for evaluating a formation fluid includes the steps of drilling a borehole intersecting a formation with a drill string, circulating a drilling fluid in the wellbore, selectively liberating a formation fluid from the formation, injecting the liberated fluid into the drilling fluid returning to the surface, drawing a sample of the returning drilling fluid at the surface, and estimating at least one parameter of the drawn sample at the surface.

Abstract: A wellbore equipment handling device is disclosed. The wellbore equipment handling device can comprise a catwalk to facilitate movement of a tubular. The catwalk can include a trough to receive the tubular. The trough can extend longitudinally along the catwalk. The catwalk can also include a base to support the trough and an indexer for moving the tubular about the catwalk. The wellbore equipment handling device can also comprise a bucking unit coupled to the base. The bucking unit can be configured to couple and uncouple joints of tubulars and downhole tools. The indexer can be operable to move the tubulars to and from the bucking unit.

Abstract: According to one aspect, a drilling rig carriage is adapted to move along a drilling mast, and includes a body structure, electric motors coupled to the body structure, and pinions operably coupled to the electric motors, respectively. The pinions are adapted to engage racks, respectively. According to another aspect, a drilling mast includes a longitudinally-extending frame having a first side portion and a second side portion spaced therefrom. Racks are coupled to the frame at the first side portion thereof. According to yet another aspect, an apparatus includes a drilling mast or tower extending longitudinally along an axis, the tower including racks spaced in a parallel relation. A top drive is movable along the axis and relative to the tower. Electric motors are coupled to the top drive and movable therewith. Pinions are operably coupled to the electric motors, respectively, and engage the racks, respectively, to move the top drive.

Abstract: A method and system for performing fluid flow tracing through a medium, such as the geologic formation surrounding a subterranean borehole, or the environment around a pipe or conduit. A transparent liner is everted into the borehole. A marker fluid from the surrounding medium emerges from the wall of the borehole and is allowed to contact the liner, or a cover of the liner, to create a stain thereon that is visible with a camera lowered into the liner interior.

Abstract: A rotary slip bowl includes a tubular body having a central bore with an internal surface. The internal surface includes a tapered profile extending from a top surface to a generally straight profile. The rotary slip bowl also includes one or more umbilical grooves in the internal surface, wherein each umbilical groove is dimensioned to partially house an umbilical line. A rotary slip system includes the rotary slip bowl and a rotary slip set configured to be partially housed within the central bore. The rotary slip set includes two or more slip segments separated by spaces. One of the spaces is aligned with each umbilical groove of the rotary slip bowl. A handle is affixed to an upper end of a slip segment with the handle positioned adjacent to one of the spaces. The rotary slip system may further include a carrier for transporting the rotary slip bowl.

Abstract: A one trip system for perforating and fracking multiple intervals uses a releasable barrier. The barrier can be an inflatable. A pressure booster system is associated with the BHA so that the existing hydrostatic pressure is boosted when the gun or portions thereof are fired. After firing in one interval, the BHA is raised and the barrier is redeployed and the pattern repeats. Instruments allow sensing the conditions in the interval for optimal placement of the gun therein and for monitoring flow, pressure and formation conditions during the fracturing. Circulation between gun firings cleans up the hole. If run in on wireline a water saving tool can be associated with the BHA to rapidly position it where desired. A multitude of perforation charges mounted in the BHA can be selectively fired by selected corresponding detonator based on a predetermined sequence or surface telemetry command.

Abstract: A downhole diffuser assembly comprising a diffuser adapted to reside within a carrier sub. The diffuser assembly includes an upper mounting member mountable within the carrier sub and having an fluid inlet port, and a lower section having a diffuser screen. A plurality of cutters are removably attached to the diffuser screen, wherein the cutters are radially oriented relative to a central axis of the diffuser screen. The cutters may extend internal or external to the diffuser screen, depending on the desired downhole conditions. In a preferred embodiment, a first set of cutters is mounted at a first selected height along the central axis of the diffuser screen, and wherein a second set of cutters is mounted at a second selected height along the central axis of the diffuser screen.

Abstract: A technique facilitates performance of a perforating operation in a wellbore. The technique comprises positioning a perforating gun assembly downhole in a wellbore via coiled tubing. The perforating gun assembly has a plurality of individually controllable perforating gun sections which may be selectively fired at different well zones. An optical fiber is deployed along the coiled tubing to deliver control signals to the perforating gun assembly. The control signals enable sequential firing of the individually controllable perforating gun sections at the desired locations, e.g. well zones, along the wellbore.

Abstract: An assembly for inclusion between a drill bit and a drill string, the assembly having an overrunning clutch mechanism that disengages the drill bit from the drill string during the “slip” portion of a stick-slip cycle to allow the drill bit to freely rotate faster than the drill string. The assembly further includes a rotational vibration dampener operatively connected between the overrunning clutch and the drill bit. The vibration dampener may include a fluid chamber with viscous fluid or restrictions to fluid flow to effect dampening. During normal operation, the one-way overrunning clutch remains engaged to transfer torque between the drill string and bit, while the torsional damper is in its maximum displaced position to transfer the load. During slip, the drill bit is disengaged until its speed is lower than the drill string speed. Torsional vibration dampener dampens sudden impulse force of the overrunning clutch re-engaging.

Abstract: A pump jack system for vertically reciprocating a downhole pump in an oil and gas well. The pump jack system includes a cylinder assembly having a drive cylinder and two balance cylinders. A piston in the drive cylinder may be used to provide an upstroke of a sucker rod string of a downhole pump. The pistons in the balance cylinders may be used to provide a downstroke of the sucker rod string. Lower chambers in the balance cylinders counterbalance the lifting and lowering of the piston in the drive cylinder. The pump jack system also includes an accumulator for maintaining a relative constant fluid pressure in the lower chambers of the balance cylinders.

Abstract: A mobile auger implement is used with an auger bit and a motor for driving the bit. The implement includes an adjustable base, a central articulating section having a double 4-bar linkage connected to the adjustable base and providing a range of movement, and an auger support and control section connected to the central articulating section and providing an operator handle for guiding the bit. The double 4-bar linkage includes central, base, and distal links and four bars each having a fixed length and being connected to the central link. The first and second bars are parallel to one another at all times, and the third and fourth bars are parallel to one another at all times. The base link is unable to tilt relative to the distal link, such that the auger maintains an angular orientation. Adjustment of the adjustable base affects the angular orientation of the auger.