Abstract: A downhole catch assembly includes a catch stem having a radial protrusion to provide a landing shoulder and a catcher sub having a longitudinal central axis and the radial protrusion of the catch stem located within the catcher sub. A landing ledge extends radially inward inside the catcher sub for engagement with the landing shoulder of the catch stem. An installation bore angled relative to the longitudinal central axis enters a bottom terminus of the catcher sub offset relative to radial center of the catcher sub. The installation bore extends into the catcher sub above the landing ledge to facilitate installing the catch stem into the catcher sub.

Abstract: A float includes a body portion having a first side surface and a second side surface, an inner surface and an outer surface, the first and second side surfaces being generally planar and forming an acute angle therebetween, the inner and outer surfaces being non-planar, and the body portion configured such that when positioned laterally adjacent an inverted second float and vertically adjacent a third float, the first side surface of the float abuts a surface of the inverted second float, and the inner surface of the float engages an outer surface of the third float.

Abstract: A system may include a production valve secured in a production fluid line of a downhole tubular. The production valve is configured to control flow through the production fluid line between a wellbore annulus and a central bore of the downhole tubular. The system may further include a pilot line extending at least to the production valve from the annulus. A flow restrictor disposed within the pilot line is configured to increase fluid pressure in the pilot line. Further, the system may include a solenoid valve secured within the pilot line and configured to actuate between an open state and a closed state in response to instructions from a controller. Pressure in the pilot line is configured to rise above an actuation threshold pressure configured to close the production valve in response to formation fluid flowing through the solenoid valve in the open state of the solenoid valve.

Abstract: A system can be used to control a wellbore tool using a piezoelectric pump. The system can include a piston, the piezoelectric pump, and a solenoid valve. The piston can be positioned in a wellbore to control the wellbore tool. The piezoelectric pump can be coupled with the piston to generate differential pressure. The piston can be actuated in at least a first direction or a second direction in response to receiving the differential pressure. The solenoid valve can be coupled with the piezoelectric pump to selectively cause the piezoelectric pump to apply the differential pressure in the first direction or in the second direction.

Abstract: This invention relates to a subsea actuator with visual position indicators and associated methods for subsea energy infrastructure, such as in the oil and gas industry. The actuator may include a housing with a window, an actuation member, and a drive mechanism that moves the actuation member between at least two positions. The invention also relates to a method that involves providing a housing with a window, connecting the actuation member to a drive mechanism, and indicating the position of the actuation member through the window. This visual inspection can be performed directly or via a camera, even in the event of a power failure, using a passive, unpowered indicator. The indication can be displayed on an ROV panel, ensuring reliable remote monitoring and operation of the subsea actuator.

Abstract: A system includes a pumping unit and a base unit. The pumping unit includes a plurality of tubulars and two or more electric submersible pumps (ESPs). The pumping unit further includes a plurality of valves associated with the plurality of tubulars, the plurality of valves each independently moveable between respective open positions and closed positions, wherein respective positions of groups of valves corresponding to operational configurations selected to adjust operation of the two or more ESPs. The base unit is adapted to receive the pumping unit and includes a subsea connector for receiving a production line and directing production fluid toward the pumping unit. The base unit also includes an isolation valve.

Abstract: A solids trap module for an electrical submersible pump (ESP) of a wellbore is provided. The module includes a solids buffer and a fluid passage, the fluid passage having a first segment configured to redirect a fluid in a first angular direction relative to an axial axis, and a second segment configured to redirect at least a portion of the redirected fluid flow in a second angular direction different than the first angular direction. The first segment, the second segment, and the solids buffer are configured to cooperate to cause settling of solids entrained by the fluid flowing through the solids trap module during a period when the ESP does not operate and to re-entrain settled solids into the fluid flowing through the solids trap module when the ESP is operating.

Abstract: Systems, devices and methods enable generation and monitoring of support platform structural conditions in a manner that overcomes drawbacks associated with conventional approaches (e.g., load cells) for generating and monitoring similar operating condition information. In preferred embodiments, such systems, devices and methods utilize fiber optic strain gauges (i.e., fiber optic sensors) in place of (e.g., retrofit/data replacement) or in combination with conventional load cells. The fiber optic sensors are strategically placed at a plurality of locations on one or more support bodies of a support platform. In preferred embodiments, the fiber optic strain gauges are placed in positions within a hull and/or one or more pontoons of an offshore platform. Such positions are selected whereby resulting operating condition data generated by the fiber optic strain gauges suitably replaces data received by conventionally constructed and located load cells of an offshore platform (e.g., a TLP).

Abstract: A system may have a built hydraulic fracturing system with a plurality of devices connected together and in fluid communication with one or more wells. The system may also include at least one continuous pumping operations for one or more wells and a fracturing pumping plan provided on a software application. The fracturing plan may include instructions to perform at least one continuous pumping operations for the one or more wells. The instructions may include a sequence of valve operations to direct fluid flow through a selected path into the one or more wells.

Abstract: Systems and methods presented herein provide for cutting in a borehole or casing. A cutting device can include a first arm having a cutting blade, wherein the cutting blade has side cutting teeth and an axis of rotation that is substantially at a right angle with respect to an axis of the tool body. The cutting device can also include a second arm with a bumper. The first and second arms articulate away from the elongate body in different directions to reduce vibrations while cutting. A control device can automate the cut based on hydraulic pressure measurements. Additionally, the cutting device can also be extended or rotated on a rotary index. The cutting device can rotate around a J slot, in an example.

Abstract: An erosion prevention and sedimentation control flow-regulation device and system is provided for all customary applications addressed by conventional filtration devices such as check-dams (ditch check, channel or culvert), inlets (curb and ground), slope (hillside), perimeter control and settling and other ponds. The flow-regulation device and system is comprised of two components: (1) a heavy, irregular-shaped, hard-wearing, non-filtering, high-porosity fill media encapsulated in a heavy-duty, high-tensile mesh (the ‘high-porosity particle mix component’), and (2) an optional sheet-like synthetic geotextile material with limited permeability (the ‘low-permeability choker component’). The high-porosity particle mix component allows much larger flows of water through the device and system. The low-permeability choker component constricts or ‘chokes’ the flow of water into the high-porosity particle mix component.

Abstract: A blowout preventer stack includes an energy storage device and a remote operating vehicle (ROV) charging port coupled to the energy storage device. The ROV charging port is configured to receive port from an ROV to charge the energy storage device for the blowout preventer stack.

Abstract: A plug used in the hydraulic fracking of hydrocarbon wells. The plug, known as a frac or bridge plug, contains one or more containers housing a chemical substance such as a solid, liquid, or gel composition. The composition may constitute or include a cleaning agent, friction reducer, suspending agent, or other wellbore additive. For example, the composition may constitute or include epoxy components, resins, thermoplastics, dry add friction reducers, dry add gel, dry add pipe on pipe, similar agents, or any combination thereof. The containers can include the same chemical substance or a variety of chemical substances. During drill out of the plug, the containers rupture and release the chemical substance into the wellbore. The released chemical substance, if a cleaning agent, assists in the cleaning of the milled-plug pieces from the wellbore.

Abstract: A modularized, electric pumping unit comprising: a base structure; an electric motor mounted on the base structure; and one or more pump modules. Each of the one or more pump modules comprises a pump and a pump module structure. The one or more pump modules are configured to be removably mounted on the base structure and driven by the electric motor.

Abstract: A valve for use in a hanger body of a well system comprises a valve body. The valve body comprises an exterior surface comprising three segments. A first segment of the exterior surface is configured with a helical thread to engage a counter-threaded portion of the tubing hanger body. A second segment of the exterior surface is configured as an essentially circumferential groove to accommodate an essentially toroidal sealing member. The groove comprises essentially right angle shoulders at both intersections of the groove with the exterior surface. A third segment of the exterior surface is configured to be devoid of the helical thread, the third segment being intermediate the first segment and the second segment.

Abstract: An internal locking ring assembly for a wellhead system that includes a compact single body locking ring design that eliminates the need for a separate casing head and housing configuration or the use of numerous lockdown pins, therefore increasing the safety of the entire drilling operation. The internal locking ring includes outer and inner diameter grooves and angles to accommodate a running tool for collapsing the locking ring for positing into wellhead seats all at lower forces than what is typical due to the lower retrieving torque when trying to retrieve the packoff. Such lower retrieving torque and force allows the use of smaller cross sections of a running tool.

Abstract: A float apparatus includes a buoyant device that has an outer surface with a first end portion, a second end portion and an elongated portion. The elongated portion extends from the first end portion to the second end portion. The buoyant device is shaped and configured to attach to a conduit. The elongated portion of the outer surface has a concaved section that extends from the first end portion to the second end portion. The concaved section has a shape that complements an outer radius of the conduit with the buoyant device attached to the conduit.

Abstract: A drilling system is provided that includes a wellbore device. The wellbore device includes a housing including a bore and a seal element composed of an elastomeric material. positioned within the housing, and configured to seal the bore. The wellbore device includes a bearing assembly supported within the housing and configured to enable the seal element to rotate relative to the housing. The drilling system includes a wireless seal wear monitoring system that includes an RFID tag embedded within the seal element and an RFID transceiver and an RFID antenna disposed within a recess of the housing at an axial location adjacent the RFID tag. The RFID transceiver and RFID antenna are configured to communicate with the RFID tag and a control system. The control system is configured to determine a presence of wear in the seal element based on information provided by the RFID tag.

Abstract: A valve for use in a hanger body of a well system comprises a valve body configured for insertion into the hanger body in an axial direction and comprising an exterior surface. A first segment of the exterior surface is configured with a helical thread to engage a counter-threaded portion of a tubing hanger body. A second segment of the exterior surface is configured as an essentially circumferential groove to accommodate an essentially toroidal sealing member. The valve body further comprises at least one stop member configured to control an extent of the insertion of the valve body into the hanger body and thereby preclude threads of the counter-threaded portion of a tubing hanger body from affecting the essentially toroidal sealing member.

Abstract: A subsea system (1) connected to a subsea well (4) for boosting a process fluid flowing out of the well, comprising: —a preconditioning arrangement (2) connectable to a process fluid line from a well, wherein the preconditioning arrangement comprises at least one sensor for measuring temperature and one sensor for measuring pressure of the process fluid—means for estimating density of the process fluid based on measured temperature and pressure, —a cooler system (20, 21) comprising at least a first cooler for cooling the process fluid wherein the subsea system further comprises: —a pressure boosting device (3) arranged downstream of the preconditioning arrangement (2), the pressure boosting device having an operational window dictating operational parameter in terms of maximum and minimum allowable density of the process fluid entering the pressure boosting device (3).