Abstract: An electronic device comprises an image sensor, one or more processors, and memory storing instructions for receiving an event recording profile based on configuration data of the electronic device, the configuration data including a location type or a power type; receiving a plurality of images of a scene captured by the image sensor; detecting a trigger event based on one or more of the plurality of images of the scene; in response to detecting the trigger event, identifying an object of interest in one or more of the plurality of images of the scene; creating an event clip from the stored images that include the object of interest, wherein creating the event clip includes configuring a clip length based on the event recording profile; and providing the event clip for display.

Abstract: A pump includes a drive chamber with a drive piston and a production chamber with a production piston. The drive piston is coupled to the production piston. The pump further includes a passage in fluidic communication with the drive piston and a port fluidically coupling the passage with the production chamber. In operation, a first pressure is applied to fluid in the passage, thereby moving the drive piston. Then a second higher pressure is applied to fluid in the passage, thereby opening a valve associated with the port. In an example operation, fluid flows from the passage into the production chamber, and flushes gas out of the production chamber, thereby alleviating gas-locking. In another example operation, fluid including a treatment chemical flows from the passage into the production chamber. A surface equipment package includes a controller configured to monitor and control operation of the pump.

Abstract: A toe prepper for a downhole casing tool, and a method of fracking are presented. The toe prepper includes a ball sub and a port sub. The ball sub includes a ball j oint, a ball, and a ball seat. The ball joint has a stepped inner surface defining a receptacle. The ball seat is positionable in the receptacle, and has a ring-shaped body shaped to receivingly support the ball. The port sub includes a port j oint, ports extending through the port j oint, and port plugs positioned in the ports. The port plugs are dissolvable upon exposure to a fluid. The ball and the ball seat are shaped to prevent the passage of fluid from the ball sub and into the port sub until activated by the fluid to release the ball from the ball seat.

Abstract: A method of producing fluid from a wellbore includes operating a pump located proximate to a zone of fluid influx in the wellbore to draw a reservoir fluid from a reservoir into the wellbore at the zone of fluid influx. The pump is coupled to a tubing string extending above the pump, and a packer is coupled to the tubing string proximate to an upper end of the zone of fluid influx and seals an annular space around the tubing string. The method includes operating the pump to produce the reservoir fluid from the wellbore through the tubing string. A pump includes a drive chamber with a drive piston, a production chamber with a production piston coupled to the drive piston, and axially separated traveling valves.

Abstract: The disclosure relates to a frac plug having an uphole side and a downhole side and having a first cone, wherein the first cone defines one or more chambers within the first cone; one or more pistons each partially inserted into the one or more chambers at a first end of the one or more pistons; a second cone connected to a second end of each of the one or more pistons; a slip barrel surrounding the first cone and the second cone.

Abstract: A method of producing fluid from a wellbore includes operating a pump located proximate to a zone of fluid influx in the wellbore to draw a fluid from a reservoir into the wellbore at the zone of fluid influx. A first section of a tubing string is coupled to, and extends above, the pump, and a second section of the tubing string is coupled to, and extends below, the pump. A packer seals a first annular space around the first section of the tubing string. The method further includes operating the pump to move the fluid from the second section of the tubing string and into the first section of the tubing string.

Abstract: In an embodiment is provided a valve that includes a housing, a mandrel connected to the housing and defining an interior volume therebetween, a sleeve having a first end and a second end, the sleeve movably disposed in the interior volume, a chamber defined in the interior volume, the chamber having a first end and a second end, an inlet of a metering device coupled to the second end of the chamber, and an outlet of the metering device adjacent to the first end of the sleeve. In another embodiment is provided a method of using a valve that includes introducing pressure to a central bore of the valve such that a sleeve of the valve moves from a closed, locked position to a test position. The closed, locked position and the test position do not permit fluid communication between a central bore and an exterior of the valve.

Abstract: In an embodiment is provided a valve that includes a housing, a mandrel connected to the housing and defining an interior volume therebetween, a sleeve having a first end and a second end, the sleeve movably disposed in the interior volume, a chamber defined in the interior volume, the chamber having a first end and a second end, an inlet of a metering device coupled to the second end of the chamber, and an outlet of the metering device adjacent to the first end of the sleeve. In another embodiment is provided a method of using a valve that includes introducing pressure to a central bore of the valve such that a sleeve of the valve moves from a closed, locked position to a test position. The closed, locked position and the test position do not permit fluid communication between a central bore and an exterior of the valve.

Abstract: A method of producing fluid from a wellbore includes operating a pump located proximate to a zone of fluid influx in the wellbore to draw a reservoir fluid from a reservoir into the wellbore at the zone of fluid influx. The pump is coupled to a tubing string extending above the pump, and a packer is coupled to the tubing string proximate to an upper end of the zone of fluid influx and seals an annular space around the tubing string. The method includes operating the pump to produce the reservoir fluid from the wellbore through the tubing string. A pump includes a drive chamber with a drive piston, a production chamber with a production piston coupled to the drive piston, and axially separated traveling valves.

Abstract: A method of producing fluid from a wellbore includes operating a pump located proximate to a zone of fluid influx in the wellbore to draw a fluid from a reservoir into the wellbore at the zone of fluid influx. A first section of a tubing string is coupled to, and extends above, the pump, and a second section of the tubing string is coupled to, and extends below, the pump. A packer seals a first annular space around the first section of the tubing string. The method further includes operating the pump to move the fluid from the second section of the tubing string and into the first section of the tubing string.

Abstract: A multiplier sleeve has a releasable seat coupled to a dog within the slidable sleeve allows a single sized ball, dart, or plug to actuate several sliding sleeves. Upon actuation by properly sized ball the ball, slidable sleeve, seat, and dog move downward where the dog is no longer supported allowing the seat to move within the slidable sleeve to a point where the seat is no longer supported thereby releasing the ball. With the slidable sleeve moved downward the port or ports in the sliding sleeve is exposed. A staged port and piston assembly inserted into the ports maintain pressure within the tubular assembly to allow the ball to move through and actuate the targeted sliding sleeves.

Abstract: An embodiment of the present invention utilizes a frac plug having an extremely short length. The extremely short length minimizes the amount of dissolvable material that must be utilized in order to maintain the physical integrity of the plug without unduly deforming the cone. Relatively uniform loading of the cone is accomplished by circumferentially locking the slip sections in place during setting. A sufficient quantity of sealing material is provided by angling the slip surface to a degree that allows a sufficient quantity of elastomer or other sealing material to be used in conjunction with backup rings to prevent the sealing material from extruding down towards the slip.

Abstract: A plug is provided that includes a mandrel, a sealing element, a slip and ramp assembly, a lock ring, at least one antirotation device, and a lower ball standoff. The slip and ramp assembly have linear and radial angles allowing a mandrel wall that is thin when compared to the overall diameter of the mandrel. The sealing element is configured so that when set additional pressure from the surface increases the sealing ability of the sealing element. Antirotation devices are provided to assist in mill out. Lock ring is provided to keep the slips in their set position and a further configured so that additional downward forces increase the locking ability of lock ring. A lower ball standoff is provided so that in the event of reverse flow a ball from below is prevented from lodging within the plug and is held at the lower end of the plug were standoffs are provided to allow fluid flow around the ball.

Abstract: In an embodiment of the present invention utilizes a frac plug having a large diameter through bore wherein the through bore is at least 75% of the outer diameter of the plug. A tracer assembly is then affixed to a lower end of frac plug. The frac plug tracer assembly is run into a wellbore where the frac plug is then set, perforated, and fracked. The obstruction within the frac plug through bore is then removed. In some instances, the instruction may be a ball, dart, or other obturator and in some instances the obstruction may be a dissolvable plug. With the obstruction within the frac plug through bore removed wellbore fluids from the hydrocarbon formation may flow upward through and around the tracer assembly picking up chemical traces which are then carried to the surface to be analyzed.

Abstract: The finger or other protrusion allows downward movement of both fluid and balls, darts, or plugs through the tool or sliding sleeve until the ball, dart, or plug releases or actuates the gate. Once actuated the gate prevents further downward movement of any ball, dart, or plug past the gate while allowing fluid flow past both the gate and the ball, dart, or plug.

Abstract: A plug is provided that includes a mandrel, a sealing element, a slip and ramp assembly, a lock ring, at least one antirotation device, and a lower ball standoff. The slip and ramp assembly have linear and radial angles allowing a mandrel wall that is thin when compared to the overall diameter of the mandrel. The sealing element is configured so that when set additional pressure from the surface increases the sealing ability of the sealing element. Antirotation devices are provided to assist in mill out. Lock ring is provided to keep the slips in their set position and a further configured so that additional downward forces increase the locking ability of lock ring. A lower ball standoff is provided so that in the event of reverse flow a ball from below is prevented from lodging within the plug and is held at the lower end of the plug were standoffs are provided to allow fluid flow around the ball.

Abstract: A multiplier sleeve has a releasable seat coupled to a dog within the slidable sleeve allows a single sized ball, dart, or plug to actuate several sliding sleeves. Upon actuation by properly sized ball the ball, slidable sleeve, seat, and dog move downward where the dog is no longer supported allowing the seat to move within the slidable sleeve to a point where the seat is no longer supported thereby releasing the ball. With the slidable sleeve moved downward the port or ports in the sliding sleeve is exposed. A staged port and piston assembly inserted into the ports maintain pressure within the tubular assembly to allow the ball to move through and actuate the targeted sliding sleeves.

Abstract: A sliding sleeve is provided that includes a housing, a spinner sleeve, an inner sleeve, a collet, an actuator, and an indexer. An object passing through the interior of the sliding sleeve is caught by the actuator forcing the indexer to move linearly downward. The linear downward movement causes the indexer to rotate one halfstep at which point the object is released. The indexer, biased towards the upward position, is returned to the upper position while at the same time is again rotated half a step. Once the pre-set number of steps is reached the indexer moves upward to support the collet. With the collet supported the next object passing through the interior of the sliding sleeve is retained by the collet which in turn forces the inner sleeve to move downward. With the inner sleeve moved to the down position a flow path is opened through the sleeve from the interior to the exterior of the sliding sleeve.

Abstract: The present invention relates to an inflow control device for controlling the flow of fluid into a tubular deployed in a. wellbore comprising coupling between joints of tubulars. The inflow control device is mounted transversely through the coupling in any inflow can control devices the initial condition fluid flow between the exterior and interior of the tubular is prevented. As sufficient pressure is exerted upon the inflow control device from the interior of the tubular the inflow control device is actuated to allow fluid flow between the interior and exterior the tubular. A nozzle in the inflow control device allows fluid to pass at a preset rate. The present invention furthermore relates to a method of assembling an inflow control device according to the invention and to a completion system comprising an inflow control device according to the invention.

Abstract: The present invention relates to an inflow control device for controlling the flow of fluid into a tubular deployed in a wellbore comprising coupling between joints of tubulars. The inflow control device is mounted transversely through the coupling in any inflow can control devices the initial condition fluid flow between the exterior and interior of the tubular is prevented. As sufficient pressure is exerted upon the inflow control device from the interior of the tubular the inflow control device is actuated to allow fluid flow between the interior and exterior the tubular. A nozzle in the inflow control device allows fluid to pass at a preset rate.