Abstract: A swivel assembly includes a first member having a first throughbore, a second member having a second throughbore, a flexible joint coupled between the first member and the second member that permits at least one of the first member and the second member to rotate an unlimited number of rotations relative to the other and that also connects the first throughbore and the second throughbore such that an electrical signal pathway for receiving an electrical signal conductor is formed that extends continuously through the flexible joint and between the first throughbore and the second throughbore, and a pressure bulkhead positioned along the electrical signal pathway that divides the electrical signal pathway into a pressure exposed zone that is exposed to external pressure from the surrounding environment and a pressure isolated zone that is isolated from the external pressure.

Abstract: A downhole motor apparatus for use with a drillstring in drilling a wellbore. The downhole motor includes a power section operatively coupled with a bearing section. A drill bit is operatively connected with the bearing section. The power section has a power section housing, and the bearing section has a bearing section housing connected with the power section housing. The bearing section housing is a unitary piece having a first bend at a first bend angle. In operation the downhole motor provides three known or controlled contact points in the wellbore.

Abstract: A method for gyrocompass surveying a subsurface well according to another aspect of the present disclosure includes moving a gyrocompass sensor to a survey position along the well. The gyrocompass sensor has gyroscopic sensors (gyros) having input axes along three mutually orthogonal directions and accelerometers having input axes along the three mutually orthogonal directions. Output of the gyros and output of the accelerometers is measured. The gyros are rotated such that the input axes are oriented along opposed directions to the three mutually orthogonal directions, wherein a different gyro input axis is oriented along each opposed direction than the gyro input axis oriented along each of the three mutually orthogonal directions. Measuring output of the gyros is repeated, and at least a geodetic azimuth of the gyrocompass sensor is determined using the measured gyro output, the repeated measured gyro output and the measured output of the accelerometers. The azimuth is corrected for gyro bias.

Abstract: An expandable downhole device may be used for supporting a wellbore and as a flow/sand control device. The expandable downhole device is initially RIH in a compressed state. Once the expandable downhole device reaches a predetermined depth in the wellbore, the expandable downhole device is transitioned from the compressed state to an expanded state to support the wellbore from collapsing. In the expanded state, an activation chamber of the expandable downhole device is expanded from a collapsed state to press an outer shroud of the expandable downhole device against the wellbore. A shape memory foam of the expandable downhole device is also expanded and hardens in the expanded state. The shape memory foam acts as a support layer for the activation chamber to provide additional support for the wellbore. The shape memory foam may be a porous material to be a filter media of the expandable downhole device.

Abstract: A hydrostatically compensated modulator assembly and method for generating pressure wave fluctuations in drilling fluid flow are disclosed, enabling advanced downhole telemetry. The assembly includes a housing, fluid passages, a hydraulic oil-filled chamber, and reciprocating members operatively connected to obstruction portions that modulate flow by transmitting lateral movement while allowing axial freedom. Kinetic energy from drilling fluid is diverted to the chamber body, reducing stress on moving actuator components. A piston is positioned at the lower chamber portion with its base directly exposed to drilling fluid, maintaining approximate hydrostatic balance between oil pressure in the chamber and drilling fluid pressure outside. A motor and gearbox-driven actuator enables high-speed signal generation.

Abstract: Systems and methods for forming perforations in a wellbore include: a laser source operable to generate a laser beam; a perforating gun with shaped charges of at least two different sizes, the perforating gun controllably rotatable relative to the wellbore when deployed; and a cable extending between the laser source and the perforating gun, the cable including at least one fiber optic cable to carry the laser beam from the laser source to the perforating gun.

Abstract: A perforating gun with a primary housing and secondary housing. The primary housing has two cutouts along its axial length. The secondary housing has a flexing element and a spring and is configured to insert into the primary housing. The flexing element has a protrusion on an exterior surface and the protrusion has an angled surface and extends radially outward from the secondary housing. The protrusion is shaped to slot into one of the cutouts when the secondary housing is inserted into the primary housing. The protrusion slots into the first of the cutouts to disarm the perforating gun. The protrusion slots into the second of the cutouts to arm the perforating gun. The perforating gun additionally includes a detonator coupled to an interior surface of the secondary housing.

Abstract: Some implementations include a packer comprising: an upper mandrel; at least one seal coupled with the upper mandrel and configured to radially expand into a casing of a wellbore; a prop configured to axially traverse, in response to hydraulic pressure, along the upper mandrel and cause the seal to radially expand; at least one shear screw configured to hold the prop stationary and in contact with the upper mandrel until sheared; and a snap ring coupled with the prop and configured to prevent axial traversal of the prop along the upper mandrel and radial expansion of the seal.

Abstract: A downhole system for conveying an explosive tool within a wellbore and reducing damage to other tools of the downhole system. The downhole system comprises a downhole tool string configured for conveyance within a wellbore, wherein the downhole tool string comprises upper tools, a lower tool comprising an explosive charge, and a sub between the upper tools and the lower tool. The sub is configured to attenuate a shock wave caused by the explosive charge when detonated to thereby reduce damage to the upper tools caused by the shock wave. The sub comprises an axial bore and a plurality of radial bores extending between the axial bore and a space external to the sub.

Abstract: A ballistic interrupt assembly may include an interrupt, a magnet coupled to the interrupt, an activator block formed of a magnetizable material and configurable between a non-magnetized state and a magnetized state, a bias element provided between the magnet and the activator block. A bias force of the bias element may be greater than a first magnetic attraction force between the magnet and the activator block in the non-magnetized state. The bias force of the bias element may be less than a second magnetic attraction force between the magnet and the activator block in the magnetized state.

Abstract: A drill bit may include a bit body having a bit axis about which the bit body is configured to rotate in a rotational direction. A drill bit may include a roller cone connected to the bit body and having a cone axis around which the roller cone is configured to rotate, the roller cone having a plurality of cutting inserts positioned in a surface of the roller cone, wherein the plurality of cutting inserts form a rolling cutting profile when rotated in around the cone axis. A drill bit may include a blade having a plurality of fixed cutting elements coupled thereto, wherein the plurality of fixed cutting elements define a fixed cutting profile, wherein the rolling cutting profile has an exposure above the fixed cutting profile and the exposure increases in a bit radial direction away from the bit axis.

Abstract: An earth boring rotary bit and method of manufacturing the same is provided. The rotary bit is intended for rotary drilling and includes a bit body having three uniform legs and three uniform rolling cone cutters rotatably mounted to the legs. The three cone cutters have a uniform angular offset (Ao) and a linear offset (Lo). Further, the magnitude of the angular offset is 2-17° and the magnitude of the linear offset is 1.6-18 mm.

Abstract: An inflatable packer assembly that includes opposing end fittings by which the inflatable packer assembly is installable within a downhole tool string. An inflatable body coupled between the end fittings has an external groove. An elongation sensor is fixed in the external groove. The elongation sensor includes a capacitive element that whose capacitance varies based on elongation of the elongation sensor in response to inflation of the inflatable body.

Abstract: Systems and methods are disclosed herein for performing a milling operation within a wellbore in an oil-and-gas setting. An example system can include a milling tool, which can include a cutting head, a linear actuator configured to advance the cutting head, and a linear displacement measurement sensor associated with the linear actuator. The sensor can be configured to measure linear displacement of the linear actuator. The system can also include a cable to lower the milling tool, a control unit that receives data from the sensor, and a display device that displays a visualization of the data from the sensor. The control unit can analyze the data to determine a location of a milling target, a status of the milling operation, and undesirable milling conditions down hole. The control unit can perform a remedial action, such as by turning on a pump to remove debris from the wellbore.

Abstract: A downhole system may include an insert frame securable within a central bore of a tubing retrievable safety valve that has driver magnet configured to project a magnetic field and move axially along a control line in the tubing retrievable safety valve. The downhole system may include an insert flapper connected to the insert frame and configured to actuate between an open position and a closed position to control fluid flow through the central bore. The downhole system may include an insert flow tube configured to move along the central bore to drive the insert flapper between the closed position and the open position. Further, the downhole system may include a follower magnet secured to the insert flow tube and magnetically engaged with the driver magnet. The follower magnet is configured to move in response to movement of the driver magnet to drive movement of the insert flow tube.

Abstract: The present invention includes a gin pole which can rotate and includes a traveling boom. The gin pole of the present invention can pick up and lay down joints of drill pipe, tubing and casing on plug and abandonment operations, while being independent of the crane.

Abstract: A system for containing well pressure including a well, a well casing, a blowout preventer (BOP), and a fuel container fluidly connected to the BOP that contains a fuel composition. The fuel composition auto ignites at a temperature between 150° F. and 1100° F. The fuel container of the system is configured to transfer heat from outside the fuel container to inside. A method for containing well pressure including heating a fuel container fluidly connected to a BOP and containing a fuel composition, autoigniting the fuel composition, producing a pressurized gas from a reaction activated by the autoignited fuel composition, directing the pressurized gas from the fuel container to a first volume of a ram casing of the BOP, expanding the pressurized gas in the first volume, driving the ram piston into a second volume of the ram casing, and driving a ram head or annular ram thereby sealing the well.

Abstract: A seal apparatus for use as sealing devices for downhole applications in a wellbore, such as packers and bridge plugs, includes a seal element formed from an elastomeric material. The seal apparatus may include one or more end pieces, referred to as extraction limiting assemblies, which are provided to limit extrusion of the sealing element in direction(s) other than in a radial direction outward from the longitudinal axis of the tool body of the seal apparatus. The end pieces may include components included in a fabric barriers sleeve that encases components of the end caps, the fabric reinforcement barriers allowing for the expansion and contraction of the end caps and the sealing element but limiting or completely blocking debris from entering into any portion of the end caps.

Abstract: The subject matter disclosed and claimed herein, in one embodiment thereof, comprises a Stri-Lube device. The device is a specialized component for sucker and polished rods, designed to reduce burning of stuffing box packing elements. The Stri-Lube device comprises a body component that supplies clean oil and inhibitors in the right quantities to reduce corrosion and costly damage. The body component features a cover that covers the internal chambers of lubricating oil and corrosion inhibitors underneath a stuffing box to connect with the wellhead. The device also features adjusting screws to tighten rubber gaskets and accommodate longer wear life. Thus, once the device is connected to a wellhead, clean oil and inhibitors in the correct quantities can be supplied to reduce corrosion, damage, and burning.

Abstract: Systems, assemblies, and methods for completing a wellbore. A wellbore completion assembly has a production tubing, a first nipple, a first electrical connection, a second nipple, and a second electrical connection. The first nipple is positioned at a first location in the production tubing. The first nipple defines a first nipple profile. The first electrical connection is positioned at the first location. The first electrical connection is configured to couple to a first electrical submersible pump assembly. The second nipple is positioned at a second location in the production tubing. The second location is different than the first location. The second nipple defines a second nipple profile different than the first nipple profile. The second electrical connection is positioned at the second location. The second electrical connection is configured to couple to a second electrical submersible pump assembly.