Abstract: A well screen assembly may be used for flow and sand control in a tubing string within the wellbore in downhole operations. The well screen assembly includes at least two filtration layers are disposed around a base pipe. Each filtration layer is configured to filter particulates from the fluid as the fluid flows through the filtration layers and into a bore of the base pipe. Additionally, outer shrouds are disposed about respective filtration layers and removably coupled to the base pipe. The outer shrouds can be solid outer shrouds for blocking fluid communication between an exterior of the outer shroud and the filtration layer or perforated outer shrouds for allowing fluid communication between the exterior and the filtration layer. The outer shrouds are interchanged to allow the use and blocking of different filtration layer.

Abstract: An apparatus, system, and method for the simultaneous remote control and monitoring of multiple wells. A main housing houses a plurality of hydraulic controls sets, each set of hydraulic controls corresponding to the fluid control valves of a well being controlled by the system. The controls are controlled by a programmable logic controller via solenoids. A control station housing houses a control station with separate touch screens for each well being controlled. The user can open and close the fluid control valves of each well using the corresponding touch screen. The touch screen also displays data for each well that is collected by a series of sensors throughout the well. The system can be pre-programmed with pre-approved valve sequences and/or safety alerts that are triggered based on the data collected by the sensors.

Abstract: A pumping system includes an electric fracturing device and multiple power supply systems. The electric fracturing device includes a plunger pump, a main motor for driving the plunger pump, and at least one auxiliary electric device. The multiple power supply systems include at least one main power supply and at least one auxiliary power supply. The main power supply supplies electric power to the main motor, and the auxiliary power supply supplies electric power to the at least one auxiliary electric device.

Abstract: Some implementations include a modular gun system for use in a wellbore comprising one or more charge segments each including a first electrical conductor having a first set of integrated electrical contacts.

Abstract: A downhole tool includes a mandrel, a slip, a sealing element, and a fluid reservoir. The slip is configured to selectively extend radially outwardly from the mandrel to facilitate engagement with a wellbore for setting of the downhole tool thereto. The sealing element is configured to selectively extend radially outwardly from the mandrel to facilitate engagement with a wellbore for creating a seal therebetween. The fluid reservoir is configured to store a fluid onboard the downhole tool.

Abstract: A wireline release tool may include a casing configured to couple to a wireline and a connector configured to couple to a tool string. The casing may have a first end, a second end, and a chamber therebetween, and the connector may be detachably attached to the second end of the casing. A gas generator may be disposed in the chamber and may be capable of generating gas pressure in the chamber sufficient to overcome a pressure differential between the chamber and the external wellbore environment and to detach the connector from the casing.

Abstract: A sand separation system for continuous sand disposal is disclosed. It includes a sand catching vessel to receive a multi-phase fluid stream (e.g., oil and gas production) containing settleable solids such as sand. A siphoning conduit connected to the vessel's lower end facilitates for continuous sand disposal. Continuous sand disposal is an operational improvement over conventional batch sand disposal systems. The separation system may feature a control valve on the siphon conduit to regulate sand flow and a water inlet to inject water into the sand collecting vessel. This continuous sand disposal design improves operational efficiency by avoiding separator downtime caused by batch removal of accumulated sand.

Abstract: A completion string includes a first casing string including a bell end, a second casing string received within the bell end, and an anchor latch mechanism having a first latch portion and a second latch portion. The insertion of the second casing string into the bell end engages the second latch portion with the first latch portion to connect the first casing string to the second casing string. A shear pin retains the anchor latch mechanism. An annular release mechanism in the second casing string includes an atmospheric chamber disposed radially within the second casing string and a piston sleeve defining a portion of the atmospheric chamber. The piston sleeve is axially shiftable upon application of external annular pressure against the atmospheric chamber shearing a shearable connection, such that the piston sleeve axially shifts to disengage the anchor latch mechanism.

Abstract: A modular fixed cutter drill bit for drilling an earthen formation has a central axis and a cutting direction of rotation about the central axis. The drill bit includes a bit body configured to rotate about the central axis in the cutting direction of rotation. The bit body includes a bit face. In addition, the drill bit includes a blade extending radially along the bit face. The blade has a leading side relative to the cutting direction of rotation, a trailing side relative to the cutting direction of rotation, and a cutter-supporting surface extending from the leading side to the trailing side. The blade includes a socket extending from the leading side of the blade and penetrating the cutter-supporting surface of the blade. The socket has a central axis, an open end at the leading side of the blade, and a closed end distal the leading side of the blade. Further, the drill bit includes a cutter element assembly removably mounted to the blade and extending from the cutter-supporting surface of the blade.

Abstract: A drilling tool, in particular a rock drill, extends along a longitudinal axis and includes a drill head, an insertion end, a main body, a cover element, a transport region which is located between the drill head and the insertion end, and at least one transport channel which extends along the transport region. The transport channel is located radially between the cover element and the main body. The cover element includes at least one interior region, which is located inside the main body, and at least one exterior region which is located outside the main body.

Abstract: A gas lift mandrel having a valve assembly that is installed and operably coupled to a well tube wherein the mandrel is installed in alternate quantities in a vertical arrangement on the well tube. The mandrel includes a body having a wall member and an interior volume. Disposed within the interior volume is a valve assembly having a sleeve member wherein the valve assembly is movable between a first position and a second position. A gas capillary tube member is operably installed wherein a second end is sealably secured to a burst disc member and a first end is operably coupled to a hydraulic pump located on the surface. In its first position the valve assembly allows gas to enter a gas aperture and exit through a passage formed in the body. In its second position the valve assembly moves to inhibit fluid flow through the gas aperture and passage.

Abstract: A method, device, and system is described herein for pushing a rotary drill bit. Pushing the rotary drill bit can include receiving a target direction in a formation to push the rotary drill bit while drilling a wellbore in a formation. Pushing the rotary drill bit can also include opening, at a first rotational position of a rotary bit pushing device disposed proximate to the rotary drill bit within the wellbore, a first inlet port of a first flow regulator. Pushing the rotary drill bit can further include closing, after the first rotational position of the rotary bit pushing device, the first inlet port. Pushing the rotary drill bit can also include sending, to a second flow regulator of the rotary bit pushing device, a second quantity of drilling fluid.

Abstract: In some implementations, the process may include securing, via an elevator, the tubular where the elevator is connected to a lifting mechanism by two or more spring bail cylinders in a retracted configuration. In addition, the process may include lifting the tubular via the elevator and converting the two or more spring bail cylinders to an extended configuration by the weight of the tubular. The process may include aligning the tubular with a member of the CRT at a top of the tubular, aligning the two or more spring bail cylinders around the CRT, and lowering the tubular to shift the weight of the tubular to a bottom of the tubular. Moreover, the process may include lowering the CRT and the two or more spring bail cylinders while simultaneously converting to the retracted configuration while maintaining alignment of the member of the CRT with the top of the tubular.

Abstract: Some implementations include a downhole line capture device for use in a wellbore comprising a ring including one or more flutes configured to enable fluid to flow axially through an annular space between the ring and a tubular; and a line retainer coupled with the ring to capture a line running along an outer surface of the ring.

Abstract: Provided is a flow control assembly, a method and a well system. The flow control assembly, in one aspect, includes a sliding piston assembly located in a piston chamber, the sliding piston assembly movable between a run-in-hole state and an activated state. In at least one aspect, the sliding piston assembly is configured to: 1) keep a flow control housing plug member within a flow control housing flow nozzle chamber and prevent fluid flow from an annulus of a wellbore to an inside diameter (ID) of a downhole tubular when the sliding piston assembly is in a run-in-hole state; and 2) allow the flow control housing plug member to traverse into the piston chamber and allow fluid flow from the annulus of the wellbore to the inside diameter (ID) of the downhole tubular when the sliding piston assembly is in the activated state.

Abstract: The position of a droppable object (e.g., a cementing plug or drillpipe dart) in a cased wellbore may be determined in real time during a cementing operation. A pressure data acquisition system is installed at a wellsite and a pressure transducer is installed at the wellhead. As the droppable object travels through casing it encounters regions with a positive or a negative change of inner cross-sectional dimension. The droppable object generates a pressure pulse as it passes through the regions. The pressure pulse and associated reflections are detected by the pressure transducer, and the signals are processed mathematically to determine the position of the droppable object. Special casing joints may be installed that comprise positive dimensional upsets that have a size of at least 3 mm. Such upsets may ensure the generation of pressure pulses of sufficient magnitude for detection by the pressure transducer.

Abstract: A method can include receiving data acquired via a drillstring in a borehole in a subsurface environment; determining boundary locations for formations in the subsurface environment using at least a portion of the data, where an end of the borehole is disposed in one of the formations; determining extended boundary locations in the subsurface environment for a region beyond the end of the borehole using the boundary locations; determining a target location in the region; generating a trajectory from an end of the borehole location to the target location; and executing a directional drilling system to control directional drilling of the drillstring that extends the borehole beyond the end of the borehole towards the target location.

Abstract: An illustrative modular manifold system includes, among other things, two or more modular pump manifolds, a low-pressure header, and a main high-pressure manifold. Modular pump manifolds may include a low-pressure manifold for supplying fracturing fluid or water to pumps, a high-pressure manifold for supplying fracturing fluid or water to one or more wells and a bleed-off/prime-up manifold. Each modular pump manifold of the modular manifold system is configured to be fluidly isolatable from the other modular pump manifolds. Each isolated modular pump manifold is configured to be flushed with water, bled off and primed up independently of the other modular pump manifolds. After the bleed off, maintenance procedures may be performed on pumps associated with the isolated modular pump manifold. The modular pump manifolds that are not isolated may continue in active fracing stage operations while a modular pump manifold is isolated.

Abstract: A vibratory tool for use in a subterranean well can include an outer housing, an insert configured to produce vibrations in a tubular string in the well, and a release member that releasably secures the insert in the outer housing. A method for use with a subterranean well can include connecting at least one vibratory tool in a tubular string, the vibratory tool including an insert releasably secured in an outer housing, positioning the tubular string in the well, then releasing the insert from the outer housing in the well, and displacing the insert through the tubular string.

Abstract: A computer-implemented method for quantifying and assessing hydrogen shows in geological formations includes receiving raw advanced mud gas data including hydrogen gas and total hydrocarbon concentrations for one or more geological formations in a geographical area, calculating a baseline concentration value of hydrogen gas for each geological formation and removing said baseline concentration value from the raw advanced mud gas data, constructing corrected hydrogen gas concentration curves via cleaning of the raw advanced mud gas data, transforming the corrected hydrogen gas concentration curves into corresponding hydrogen gas concentration indices to categorize hydrogen shows by strength, and grouping the hydrogen gas concentration indices by geographical location to identify potential sources of hydrogen gas for extraction operations.