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.

Abstract: A bit for drilling a wellbore includes: a body; and a crown. The crown includes: a cone section and a shoulder section; a plurality of blades protruding from the body, each blade extending from a center of the crown and across the shoulder section; and a row of superhard cutters mounted along each blade, each cutter mounted in a pocket formed adjacent to a leading edge of the blade. Each row has a plurality of inner cutters located in the cone section. Each inner cutter has an inclined face oriented to decline toward the center of the crown for creating an effective negative side rake angle while drilling with the drill bit and a weight on bit (WOB) reducing effect. Each of the rest of the cutters are oriented such that an overall effect for the bit is the WOB reducing effect.

Abstract: Systems, methods, and apparatus for implementing a downhole motor assembly in a well system. The downhole motor assembly may include a first tubular housing configured to house a first portion of the downhole motor assembly, and a second tubular housing configured to house a second portion of the downhole motor assembly. The second tubular housing may be configured to axially join with the first tubular housing. One or more radially disposed fasteners may be coupled with the first tubular housing and the second tubular housing. The one or more radially disposed fasteners may be configured to secure a joint between the first tubular housing and the second tubular housing. Each of the one or more radially disposed fasteners may include a threaded portion and a cylindrical portion.

Abstract: A charge assembly includes a charge tube, shaped charges, and propellant charges. The charge tube is positionable in a downhole perforating tool. The shaped charges and the propellant charges are receivably supported in the charge tube. Each of the shaped charges includes a charge jacket and a charge material. The charge material has a detonation rate of greater than one microsecond. Each of the propellant charges includes a propellant jacket and a propellant material. The propellant charges have a detonation rate of less than one microsecond. An uphole portion of the propellant charges are positioned uphole from the shaped charges and a downhole portion of the propellant charges are positioned downhole from the shaped charges. The shaped charges are positioned between the uphole and the downhole portion. The shaped and the propellant charges are electrically connectable to a detonator for activation thereby.

Abstract: Provided herein is a system for determining a radius of invasion of a drilling fluid. The system can include a formation tester tool and at least one processor. The formation tester tool can be operable to be positioned in a wellbore. The formation tester tool can be operable to measure at least one property of a formation fluid within the wellbore. The at least one pump can be operable to pump a drilling fluid into the wellbore. The at least one processor can be configured to receive the at least one property of the fluid within the wellbore, a drilling pressure, a formation pressure, and at least one property of the drilling fluid, receive a drilling schedule including at least one change in an downhole environmental condition, and determine a radius of invasion of the drilling fluid based on the at least one property of the fluid, the drilling pressure, the formation pressure, the at least one property of the drilling fluid, and the drilling schedule.

Abstract: A tool may include a body having a rotational axis oriented in an axial direction. A tool may include a sensor positioned proximate to a window in a radially outward surface of the body, wherein the window defines a window outer diameter relative to the rotational axis. A tool may include a plurality of stabilizer pads positioned on the outward surface of the body in a downhole direction of the axial direction relative to the window, wherein the plurality of stabilizer pads defines a pad outer diameter relative to the rotational axis that is greater than the window outer diameter.

Abstract: Methods and systems are disclosed that use a temperature sensor integral to a drill bit while drilling. The temperature sensor is configured to measure temperature associated with a cutting element of the drill bit over time while drilling. The temperature sensor is used to generate time-series temperature data representing temperature of the cutting element of the drill bit over time while drilling. The time-series temperature data is processed to determine at least one condition of the wellbore and/or the drill bit while drilling, wherein the at least one condition relates to at least one of: i) detecting that a steering tool of the BHA of the drill bit is active and operating to control the direction of drilling, ii) detecting backwards whirling while drilling, and iii) detecting a transition between different types of reservoir rock while drilling.

Abstract: Apparatus and methods for coupling a rope socket with an armored cable. The armored cable includes a conductor core having one or more cables for transmitting electrical and/or optical signals and at least one layer of armor wires wound around the conductor core. The rope socket includes a housing having an uphole end through which the armored cable extends into the housing and a downhole end through which the conductor core extends from the housing to a component of downhole equipment suspended in a wellbore by the armored cable. The armor wires are arranged inside of the housing so that they are spaced apart at least locally from the conductor core. A plastic material disposed within the housing fills interstices each defined by one or more surfaces of one or more of the conductor core, one or more of the armor wires, and the housing.