Abstract: A method and system can include positioning an optical waveguide along a wellbore, and launching one or more optical signals into the waveguide at one or more optical signal frequencies and during one or more time periods, thereby resulting in one or more backscattered signals being received by the receiver, which produces a trace for each of the one of more backscattered signals. Changing an environmental condition in the wellbore, generating additional backscattered light signals at one or more frequencies after the change. Comparing the traces generated before the condition change to those generated after the change, identifying a before trace and an after trace that are substantially equal to each other and identifying a frequency difference between these traces. The frequency difference can be used to determine the amount of change in the environmental condition that occurred when the environmental change event happened.

Abstract: A method for wellbore directional drilling includes selecting a starting and stopping spatial position of at least one portion of the wellbore. A sequence of sliding and rotary drilling operations within the portion is determined to calculate a wellbore trajectory. The sequence has at least one drilling operating parameter. The operations include a constraint on the drilling operating parameter or the calculated trajectory. The calculated trajectory includes a projected steering response of a steerable motor in response to the at least one drilling operating parameter. Drilling the portion of the wellbore is started. A spatial position of the wellbore during drilling is determined at least one point intermediate the starting and stopping positions. Using a relationship between the projected steering response and the drilling operating parameter, the drilling parameter and/or the constraint are adjusted based on the measured spatial position and the stopping spatial position.

Abstract: A drilling system includes a rotatable string for connecting with a bit for drilling a borehole, and an active stabilizer which includes a body having an outer surface for contacting a wall of the borehole, and a plurality of actuators connecting the body and the string and capable of driving the string to deviate away from a center of the borehole with a displacement to change a drilling direction. The drilling system further includes a module for measuring direction parameters including at least one of a declination angle and an azimuth angle of the borehole, a module for measuring imbalance parameters including at least one of a lateral force, a bending moment and a torque near the drill bit, and a controller including a calculator for calculating an adjustment needed for the displacement, based on the measured parameters and expected values of these parameters.

Abstract: Automated choke control apparatus and methods are disclosed herein. An apparatus for automatically controlling a choke valve comprises a controller. The controller is to control a choke position of the choke valve via a first control loop in response to selection of a first one of a plurality of operation modes being detected. The controller is further to control a wellhead pressure of a wellhead via a second control loop in response to selection of a second one of the plurality of operation modes being detected, the wellhead being operatively coupled to the choke valve.

Abstract: A method of freeing a stuck pipe includes positioning a pipe freeing tool within the wellbore at a location proximate the stuck pipe, the pipe freeing tool including a downhole conveyance; and an arm coupled to the downhole conveyance, and activating the arm of the pipe freeing tool to apply a force to an external surface of the stuck pipe, wherein the force moves the stuck pipe away from a surface of the wellbore and towards a center of the wellbore. Another method of freeing a stuck pipe from a wellbore includes positioning a pipe freeing tool within the wellbore at a location proximate the stuck pipe, the pipe freeing tool including a jack device and a set of wheels coupled to the jack device, and activating the jack device of the pipe freeing tool to apply a force to an external surface of the stuck pipe.

Abstract: A method and system for completing cementing operations in a subterranean well with a wiper plug assembly includes delivering the wiper plug assembly into a casing, the wiper plug assembly having a wiper plug body with a circular cross section and a resilient wiper element that engages an inner diameter of the casing string. An inclination of the wiper plug assembly is measured in three dimensions with an accelerometer assembly and an azimuth of the wiper plug assembly is measured in three dimensions with a magnetometer. The inclination and the azimuth of the wiper plug assembly are delivered to a control unit in real time. An inclination of the wiper plug assembly is determined in real time. The inclination of the wiper plug assembly is delivered to an earth's surface in real time with a transmitter of the electronics package.

Abstract: A power generation device is provided. The power generation device can include a magnetic coupler. The magnetic coupler can be associated with a maximum torque output. The maximum torque output of the magnetic coupler can be based on a size of the magnetic coupler. The power generation device can also include an alternator coupled to the magnetic coupling device. The alternator can convert kinetic energy received from the magnetic coupling device into a current. The kinetic energy can be generated by the magnetic coupler using a rotational force transferred across the magnetic coupling device. The power generation device can also include a power converter device coupled to the alternator to shape the current from the alternator such that the maximum torque output is sufficient to cause the power converter to output a threshold current sufficient for operating a well tool powered using the power generation device.

Abstract: The present disclosure relates generally to wellbore cleanout and, more particularly, to an improved tool used to remove debris from an interior of a tubular string. The tool may comprise a number of combinations of varying subsystems able to customize the tool to the operator's needs. A cleaning tool may comprise a body, a first centralizer, wherein the first centralizer is disposed at a first end of the body, a second centralizer, wherein the second centralizer is disposed at a second end of the body, and at least one subsystem, wherein the at least one subsystem is disposed on the body.

Abstract: An apparatus and method for downhole measurement during operation of a drilling system is disclosed.

Abstract: A jarring apparatus includes first and second jarring assemblies rotatable relative to each other. A first impact surface is provided on the first jarring assembly and a second impact surface is provided on the second jarring assembly, wherein, in use, the first and second impact surfaces are biased together. A first lifting structure is rotatably fixed relative to the first jarring assembly and a second lifting structure is rotatably fixed relative to the second jarring assembly, the first and second lifting structures being configured to cooperate during relative rotation therebetween to cause cyclical relative displacement in one axial direction to define a lifting phase and relative displacement in a reverse axial direction to define a dropping phase.

Abstract: A shear ram system includes an upper block positioned to transition from a first location outside a bore to a second location within the bore, the upper block including a blade control arm having a first contact surface. The shear ram system includes a lower block positioned to transition from the first location outside the bore to the second location within the bore, the lower block including a second contact surface proximate the first contact surface. The shear ram system includes a progressive gap between the first contact surface and the second contact surface larger at a first end than at a second end such that a first gap distance at the first end is greater than a second gap distance the second end.

Abstract: Methods of plugging a hydrocarbon well by using degradable plugs plus a degradable tape to ensure pressure testing to 10,000 psi. When the plug is no longer needed, a degradation fluid or fluids are pumped downhole and that fluid or fluids degrade the degradable plugs and degradable tape, thus avoiding the production of any solids large enough to clog or block equipment.

Abstract: A method and apparatus for detonating a power charge in downhole wellbore using a heating element embedded within the energetic material of the power charge.

Abstract: A compact setting tool that sets a packer or bridge plug in a wellbore and then self bleeds the pressure prior to pulling the string out of the wellbore.

Abstract: Various embodiments include a system to manage a tool on a conveyance from a surface of a wellbore. The system includes a remotely controllable reel to receive the conveyance about the reel and remotely controllable to distribute the conveyance into or out of the wellbore. The system also includes a crane positionable to support the conveyance between the reel and the wellbore.

Abstract: A method and apparatus for single-trip casing cutting and pulling for well abandonment and slot recovery. Perforations (28) are made in the casing (12) at a maximum depth using a punch tool (18) and a pulsed fluid circulated through the perforations (28) to determine a return at surface. In the event of a return at surface being detected, the casing (12) is cut and then pulled with assisted vibratory action. When no return is detected, perforations (28) are made at increasingly shallower depths until a return is detected and the casing (12) is then cut and pulled. This ensures the maximum length of casing (12) is cut and pulled on a single trip in the well bore.

Abstract: A method and apparatus for single-trip casing cutting and pulling for well abandonment and slot recovery. Perforations (28) are made in the casing (12) at a maximum depth using a punch tool (18) and fluid circulated through the perforations to determine a return at surface. In the event of a return at surface being detected, the casing (12) is cut and pulled. When no return is detected, perforations are made at increasingly shallower depths until a return is detected and the casing (12) is then cut and pulled. This ensures the maximum length of casing (12) is cut and pulled on a single trip in the well bore (10).

Abstract: Various embodiments of the present disclosure include a system, method, and apparatus for increased control of steam injection for use in oil and gas recovery in a well. Embodiments can comprise a plurality of controllable zones of injection disposed in the well. The plurality of controllable zones include a primary conduit that houses a plurality of concentric conduits of decreasing diameter disposed inside of the primary conduit. In some embodiments, each of the concentric conduits includes a proximal end and a distal end. In some embodiments, each of the plurality of concentric conduits are fluidly sealed from one another from their respective proximal end to distal end.

Abstract: A circulating sub having an elongate outer member and an elongate inner member positioned within the outer member. Locking members releasably maintain the inner and outer members in a longitudinally fixed relationship. The sub may be activated by a single ball. The ball engages with the locking members and unlocks the inner member from the outer member. The increase of fluid pressure within the sub causes the inner member to move downward within the outer member. Downward movement of the inner member opens exit ports on the outer member to allow fluid to flow into a wellbore surrounding the sub. The decrease of fluid pressure within the sub causes the inner member to move upward within the outer member. Upward movement of the inner member seals the exit ports and deactivates the sub. Once the sub is deactivated, the ball may be expelled from the sub.

Abstract: A method device, and system is described herein for pushing a rotary drill bit. Pushing the rotary drill bit ears include receiving a target direction in a formation to push the rotary drill bit wile drilling a wellbore in a formation. Pushing the rotary drill bit can also include opening, at a first rotational position of a rotary bit pushing device disposed proximate to the rotary drill bit within the wellborn, a first inlet port of a first flow regulator. Pushing the rotary drill bit can further include closing, after the first rotational position of the rotary bit pushing device the first inlet port. Pushing the rotary drill bit can also include sending, to a second flow regulator of the rotary bit pushing device, a second quantity of drilling fluid.