Abstract: Embodiments of a vertical pipe handler system (50) and method of its use include a casing tong handling tool (10) connected to a lifting tool (55) having a gripper head (51) and supported by an arm (53) of the vertical pipe handler system. The casing tong connection (33) of the handling tool is located toward the tool's lower end (21) and may be offset in a horizontal direction from the connection (29) to the lifting tool. The casing tong (60) then hangs off-center relative to the lifting tool. The amount of offset may be effective to prevent interference between the gripper head and a tubular being handled by the casing tong.

Abstract: A ball lift sleeve and retrieval tool comprising a sleeve for disposing in tubing of a well, the sleeve defining a first passage from a first proximal end to a first distal end, and a retrieval tool for disposing in the tubing of the well, the retrieval tool being separately moveable in the tubing between mated and unmated conditions with respect to the sleeve, the retrieval tool at least partially mating with the first distal end of the sleeve when in the mated condition and at least partially closing fluid communication through the passage of the sleeve when mated therewith.

Abstract: A flow control device including a housing sized to be disposed within a wellbore; a valve portion disposed within the housing and operable to control the flow of fluid therethrough, the valve portion having at least one valve having a first configuration and a second configuration; an actuator operable to adjust the at least one valve between the first configuration and the second configuration; and a conduit coupled with an exterior surface of the housing and in fluidic communication with the at least one valve.

Abstract: An inflow control device for controlling a production flow can include an inlet, a vortex chamber, and a flow control chamber. The inlet can extend obliquely relative to the central axis of the device. The vortex chamber can induce a vortical inflow from the inlet. The flow chamber can receive vortical inflow from the vortex chamber. A movable restriction disk within the flow control chamber can restrict the vortical inflow therein.

Abstract: A monitoring and mapping system, including: at least four transceiver devices arranged to be applied at a predefined mutual distance along a casing pipe, each of the transceiver devices including: a tubular body arranged to be fit on the casing pipe, the tubular body having at a first end a first longitudinal portion, at a second end a second longitudinal portion and a third longitudinal portion interposed between the first and second longitudinal portions; a coil wound on the first longitudinal portion; a layer of elastomeric material which winds the third longitudinal portion; an electrode wound on the layer of elastomeric material; and a peripheral electronic control unit associated with the tubular body; the monitoring and mapping system further including a central electronic control and data acquisition unit configured to drive the peripheral electronic control units so as to selectively power the electrodes and the coils.

Abstract: A system and method for systemically generating complexity through a formation may include defining a diverter schedule including a set of diverters to be pumped into a wellbore over a duration of time. The system and method may include a first diverter being pumped into the wellbore based on the diverter schedule, the first diverter including matter corresponding to a first mesh value. An onset of pressure response value may be determined using a pressure sensor during or after pumping the first diverter into the wellbore. A next diverter including particles corresponding to a second mesh value may be selected using the onset of pressure response value and the diverter schedule. The next diverter may then pumped into the wellbore.

Abstract: A perforating gun includes first and second shaped charges. Each of the shaped charges includes a case, a liner, and an explosive. Each liner has a subtended angle about an apex of the liner. A first jet formed by the first shaped charge creates a first entrance hole in a first region of a well casing, and a second jet formed by the second shaped charge, creates a second entrance hole in a second region of the casing. The second region is below the first region in the casing. A ratio of a diameter of the first entrance hole to a diameter of the second entrance hole is 1 when the subtended angle is between 100° and 110°, the ratio is less than 1 when the subtended angle is between 90° and 100°, and the ratio is greater than 1 when the subtended angle is greater than 110°.

Abstract: The object of the present invention is to create the elements and parts necessary to supply lifting energy to a motionless fluid in a fluid container, together with the capability to change the level or position where the motive fluid can be injected. It is done with a string and an artifact that utilizes the educing principle to draws forth a motionless fluid and induce its movement using another fluid (motive fluid) as a medium. The main part of the invention is this educing artifact that can be fabricated in one body without moving parts, but it also can be fabricated adding optional features such as an outer ring used as sealing mechanism around the artifact that seals the communication between the lower and the upper sides of the fluid container. The artifact operates with a fluid fed by a pumping or compression system.

Abstract: An unloading plunger having a chamber for compressed gas and a method for unloading liquid from a wellbore via ascending of the unloading plunger including ascending via formation pressure the unloading plunger from the bottom portion of the wellbore to a rest position at a wellhead and releasing compressed gas from the chamber into the wellbore during the ascending to decrease hydrostatic pressure of liquid in the wellbore above the unloading plunger.

Abstract: An unloading plunger having an internal chamber to hold compressed gas and a timer-operated valve to release the compressed gas through a gas jetting port as a jetting force for ascent of the unloading plunger in a wellbore to unload liquid from a well. The ascending of the unloading plunger may be via a combined motive force of wellbore pressure provided by formation pressure plus the jetting force provided by ejecting the compressed gas from the unloading plunger.

Abstract: Artificial lift systems, methods, and apparatuses are described. An example artificial lift system may include a plunger have an energy-storing component to store energy as the plunger descends through a wellbore and release the stored energy as the plunger ascends through the wellbore. The energy-storage component may be a spring. The spring may be compressed in response to rotation of a propeller coupled to the spring. The propeller may rotate in a first direction in response to interaction of the propeller and a liquid in the wellbore as the plunger descends. The spring may expand during uphole movement of the plunger to rotate the propeller in a second direction, opposite the first direction, and assist in lifting the plunger to the surface.

Abstract: A GLV-gas lift valve that uses dual “Fortress™” seals on both sides of the bellow 19 to protect said bellow from both high dome pressure 3 acting against outside bellow surface and high injection pressure acting against bellow 19 internal surface. When valve is in closed position, after dome pressure 3 is applied, upper-dome side “Fortress™” seal is engaged and prevents high dome pressure reaching said bellow 19 external surface. When valve is in fully open position, when injection pressure 14 is applied, lower seal 10 is engaged and prevents access of high injection pressure into bellow acting against bellow internal surface. This principle allows much higher pressures to be applied in valve dome section and injection section by reducing differential pressure across the bellow 19. In addition, lower “Fortress™” seal allows very high injection pressure 14 more than 10 KSI to be applied without damage to bellow or gas lift valve components.

Abstract: A drill string steering system includes a motor and a rotary valve body disposed in a tool body. The motor includes a motor shaft coupled to the motor and extending within a central bore of the tool body. The motor shaft has a downhole engagement portion that includes a first splined surface. The rotary valve body includes a disk-shaped component and a valve shaft coupled to the disk-shaped component and extending uphole of the disk-shaped component. The valve shaft includes a second splined surface engageable with the first splined surface for rotation of the motor shaft to be imparted to the rotary valve body.

Abstract: A pipe guide comprising a first arm comprising a first set of guides; and a second arm comprising at least one guide, wherein all guides of the first set of guides are adapted to bias against an external portion of a pipe, and wherein a pressure of each of the guides against the pipe is adapted to be above a threshold pressure necessary to guide a secondary pipe relative to the pipe. In an embodiment, the first set of guides comprises a plurality of bodies and at least one of the bodies of the first set of guides is adapted to be rotatable about a rotational axis with respect to the first arm.

Abstract: Methods and apparatus for utilizing a valve with a pump rotor passage with a downhole production string, the pump rotor being on a rotatable rod with a bobbin moving along the rod between a position for opening the passage to fluid flow, when the bobbin is not seated on a shuttle seat, and a position for closing the passage to fluid flow, when the bobbin is seated on the shuttle seat. The pump rotor and rod are removable through the passage while leaving the pump stator in place upstream of the valve.

Abstract: A screen and valve system includes a first screen portion including an inner surface and an outer surface. The inner surface defines a first conduit section. A second screen portion includes an inner surface portion and an outer surface portion. The inner surface portion defines a second conduit section. The second screen portion is mechanically joined with the first screen portion such that the first conduit section and the second conduit section form a flow path. A valve member is arranged in the flow path. The valve member includes a a first end segment, a second end segment and an inner surface defining a conduit. First end segment is arranged in the first conduit section without a mechanical connection and the second end segment is arranged in the second conduit section without a mechanical connection. A valve element is slideably arranged in the conduit.

Abstract: An apparatus and method of using drilling vibrations generated by the deformation of a rock formation in response to forces acting on the rock formation, where the forces are related to a drill bit and/or drilling fluid system, to identify the nature and occurrence of fractures, fracture swarms and other mechanical discontinuities (boundaries) such as bedding planes and/or faults that offset or otherwise separate rock formations with different mechanical rock properties.

Abstract: A wellbore drill bit includes a body that defines an inner volume and includes a top sub-assembly, and a plurality of cutting cones along a longitudinal axis of the body. The wellbore drill bit includes a chamber positioned in the inner volume of the body to form an annulus between the chamber and the body; a first set of nozzles positioned in the plurality of cutting cones, each nozzle of the first set of nozzles including a fluid entry that is fluidly coupled to a primary drilling fluid flow path, and a fluid exit oriented toward the second longitudinal end of the body; and a second set of nozzles positioned in the body. Each nozzle of the second set of nozzles includes a fluid entry that is fluidly coupled to the annulus, and a fluid exit oriented toward the first longitudinal end of the body.

Abstract: A wellbore isolation device capable of being set from the top including one or more components capable of degrading when exposed to a wellbore environment. A method and system for providing zonal isolation in a wellbore that includes a downhole degradable top-setting wellbore isolation device.

Abstract: A downhole tractor has at least one hydraulic drive section, comprising a first hydraulic supply line for actuating at least one hydraulic cylinder for actuating at least one tractor arm and a second hydraulic supply line for driving at least one hydraulic motor for rotating at least one tractor wheel. The downhole tractor further comprises a hydraulic power pack configured for supplying hydraulic fluid to the hydraulic supply lines. The hydraulic power pack comprises a pressure-setting valve provided in between the first hydraulic supply line and the second hydraulic supply line, wherein the pressure-setting valve is configured for feeding excess hydraulic fluid in the first hydraulic supply line to the second hydraulic supply line to increase the speed of the downhole tractor.