Abstract: The present invention is related to a downhole tool having a flapper valve assembly for controlling the backflow of fluid into a tubing string. The downhole tool includes a first sleeve slidably disposable within at least a portion of the flapper valve assembly and the downhole tool. The downhole tool can also include a second sleeve slidably disposed within the downhole tool. The present invention is also related to a method of using the downhole tool. The method includes the step of positioning the downhole tool in a wellbore. Once the downhole tool is positioned in the wellbore, the first sleeve is shifted to interact with the flapper valve assembly.

Abstract: A drilling machine for a wellbore is provided. The drilling machine may include a dynamic lateral pad that is movable between an extended and retracted position. In the extended position, the pad moves the drill bit in a direction for drilling. The drilling machine may include a dynamic lateral cutter that is movable between an extended and retracted position. In at least the extended position, the cutter engages the wellbore and removes formation. The drilling machine may include a monolithic or integral drill bit/drive shaft to reduce the distance between a positive displacement motor and a distal end of the monolithic or integral drill bit/drive shaft. The drilling machine may include separate cutting structures that have different rotational speeds and can further utilize the integral drill bit/drift shaft and/or a bent housing that generates an off-axis rotation which helps optimize the formation removal in the center area of the wellbore.

Abstract: A connection assembly for automated lifting and positioning of a chiksan or other fluid conduit in proximity to a fluid inlet of a device such as, for example, a cement or hydraulic fracturing head. Once a chiksan or other flow line is positioned in a desired location, a secure connection is made between the outlet of the chiksan or other fluid conduit and the fluid inlet including, without limitation, when the device is positioned at an elevated location above a rig floor.

Abstract: A disclosed example embodiment includes a drill bit used to form wellbores in subterranean formations. The drill bit includes a drill bit body for coupling to a lower end of a drill string. The drill bit body includes at least one support arm having an inwardly extending journal with a journal bearing having at least one radially reduced pocket extending at least partially circumferentially around the journal bearing including a load side of the journal bearing. At least one rotary cutter assembly is rotatably mounted to the journal. A plurality of cutting elements is disposed on the at least one rotary cutter assembly. At least two independent hardmetal pads are positioned within the at least one radially reduced pocket such that the hardmetal pads have a gap disposed therebetween.

Abstract: The present invention is related to a downhole tool having a flapper valve assembly for controlling the backflow of fluid into a tubing string. The downhole tool includes a first sleeve slidably disposable within at least a portion of the flapper valve assembly and the downhole tool. The downhole tool can also include a second sleeve slidably disposed within the downhole tool. The present invention is also related to a method of using the downhole tool. The method includes the step of positioning the downhole tool in a wellbore. Once the downhole tool is positioned in the wellbore, the first sleeve is shifted to interact with the flapper valve assembly.

Abstract: A system and method for building and handling oilfield tubular stands while drilling operations are simultaneously and independently occurring with one drilling deck, one derrick, and one rotary system. An offline guided path horizontal to vertical arm lifts and moves in the same plane tubulars stored horizontally on the catwalk and positions the tubulars vertically directly into a preparation hole for assembling and disassembling tubular stands while online drilling operations are simultaneously being conducted. A stand arm lifts and lowers the tubulars into and out of the adjustable preparation hole, and transports the tubulars for storage to an auxiliary tubular racking station in the upper part of the derrick. A bridge racker crane moves tubular stands from the auxiliary tubular racking station to the top drive or another tubular racking station.

Abstract: A downhole hydra-jetting apparatus has a substantially cylindrical guide housing having an outer surface and an inner surface, and defining a cavity longitudinally extending through the guide housing; a plurality of retractable guide members attached radially around the guide housing; and a substantially cylindrical jet housing having an outer surface and an inner surface, and defining a cavity longitudinally extending through the jet housing, with a plurality of jetting nozzles defined in, and radially positioned about, the jet housing. Each of the plurality of jetting nozzles are adjustable relative to the guide housing to allow substantial alignment of projections from the plurality of jetting nozzles and the plurality of guide members when the guide members are extended radially from the outer surface of the guide housing and the apparatus is actively moved through a downhole.

Abstract: A crossover valve assembly for insertion into production tubing, or integral with production tubing, includes an outer housing, an inner production tube, a pilot section responsive to external pressure to open an activation passage above a pre-determined pressure, a power section responsive to pressure in the activation passage to open an injection opening; and a crossover valve responsive to pressure in the injection opening to open a crossover port, allowing fluid communication from outside the outer housing to within the inner production tube.

Abstract: In one embodiment, an anti-rotation system includes a first tubular member having an extended thread and a torque shoulder, the first tubular member comprising a radial recessed area, the radial recessed area located axially between the external thread and the torque shoulder of the first tubular member. The system may further include a second tubular member comprising a radial recessed slot, the radial recessed slot located in the inner circumference of the second tubular member. The system may also include a pin toothed insert mechanically coupled to the first tubular member within the recessed area, the pin toothed insert comprising a first circumferential tooth pattern facing radially outward from the first tubular member. The system may also include a spring loaded, radial ratchet dog located within the radial recessed slot, the spring loaded radial ratchet dog comprising a second circumferential tooth pattern facing radially inward from the second tubular member.

Abstract: An actuator assembly for effective interventionless activation of a valve in wells of multilateral architecture. The assembly may be pressure actuated from an oilfield surface even in certain circumstances where another valve in another leg of the well has been opened in a manner compromising pressure control of the well. Due to the multi-stage nature of the actuator, pressure based activation remains viable as a result of supplemental and/or fail-safe modes of actuation, for example, where such pressure control becomes compromised.

Abstract: A well system includes a local control unit configured to communicably couple to a well shut-in assembly at a well site, the well shut-in assembly operable to shut-in a wellbore based on a command from the local control unit; and a remote control unit configured to wirelessly communicate a line-of-sight airborne wireless signal, at a location remote from the local control unit and the well site, to initiate the command from the local control unit to the well shut-in assembly.

Abstract: A shoulder includes a shoulder body having a plurality of J-slots disposed circumferentially about the shoulder body at a first axial end of the shoulder body, a retainer ring disposed about the shoulder body having an exterior threaded surface and an annular lip, a load ring having a threaded interior surface configured to interface with the threaded exterior surface of the retainer ring and a tapered bottom surface, and a lock ring having a tapered bottom surface configured to interface with the tapered bottom surface of the load ring such that when the load ring moves axially toward the lock ring, the lock ring radially expands and when the load ring moves axially away from the lock ring, the lock ring radially contracts.

Abstract: The present invention relates to a downhole system for unloading a liquid of a well in an annulus between an intermediate casing and a production tubular metal structure.

Abstract: Provided are systems and method for operating and maintaining downhole inflow control valves (ICVs) of hydrocarbon wells, including monitoring the operations of ICVs to identify failure and non-failure times of defective and non-defective ICVs, respectively, determining a probability of failure of the ICVs (Pf) based on the failure and non-failure times, determining an operational stroking duration based on the probability of failure of the ICVs (Pf), and operating ICVs in accordance with the operational stroking duration determined.

Abstract: A method and apparatus are provided for controlling wellbore pressure within a wellbore during a perforation event by changing a state of a valve system multiple times. Information generated about the wellbore pressure within the wellbore may be received. A state of the valve system, which is positioned relative to a chamber within the wellbore, may be changed multiple times based on the information received to create a plurality of pressure conditions that substantially match a reference pressure profile. Each of the plurality of pressure conditions is selected from one of an underbalance condition and an overbalance condition.

Abstract: Disclosed examples include a ball drop tool located in a drill string. The ball drop tool may be a drilling stabilizer that includes a drilling stabilizer housing having an interior passage to be coupled to a drill string. A at least one stabilizing blade is on an external surface of the housing. The stabilizing blade includes a hollow compartment to hold at least one ball. A gate valve couples the hollow compartment of the stabilizing blade to the interior passage. Gate valve circuitry is coupled to the gate valve for controlling operation of the gate valve to controllably release one or more of the balls.

Abstract: An external trap apparatus (70) and a method for safely controlling drilling tool string components during oil field drilling operations includes a collar clamp (72) affixed to a drilling tool string lubricator (80) and configured with laterally spaced first and second vertical rails (120, 122) depending therefrom and configured to support a coaxially aligned guide plate (232) and a reinforced catcher plate assembly (164) carrying a tool-end receiving funnel receptacle (202) and first and second energy absorbing crush cylinders (160, 162). When the drill string (82) is raised or withdrawn from the well (28), the funnel receptacle (202) can be rotated into coaxial alignment to catch the drill string's end or downhole tool, in the event of an inadvertent loss of control of the drill string (82).

Abstract: A technique facilitates servicing of a subterranean formation by treating a specific section of a well. The technique utilizes a straddle packer conveyed downhole and then activated via coiled tubing. The straddle packer comprises a first, e.g. upper, packer and a second, e.g. lower, packer which are deployed downhole into the wellbore to the specific section of the wellbore proximate a target formation zone. Once properly located, the straddle packer is uniquely activated by compression and tension inputs applied via the coiled tubing.

Abstract: A system for obtaining a core sample from a wellbore includes a housing having a core opening at a first end of the housing and an end wall at a second end of the housing. A balancing piston is positioned within the housing to define a sample chamber between the balancing piston and the core opening. An equalization chamber is defined between the balancing piston and the end wall. A core piston is sealingly positioned in the core opening.

Abstract: A method includes coupling a strain gauge to a tubular member, and positioning the tubular member in the wellbore such that the tubular member is placed under bending stress by a curvature or deviation in the wellbore. The method also includes measuring bend on the tubular member with the strain gauge in at least one plane and determining one or more of the magnitude or orientation of the curvature of the wellbore based on an output of the strain gauge.