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: Apparatus and methods for protecting a submersible pump. The apparatus can include a cage having at least two longitudinal support arms, at least one window defined between any two of the support arms, and a perforated insert is at least partially disposed within the cage, wherein a first end of the perforated insert has a seat formed therein for engaging a moveable member that is contained within the cage, wherein passage of solids, fluids or both through the flow path is at least partially restricted in a first flow direction when the moveable member contacts the seat of the perforated insert and passage through the flow path is not restricted in a second flow direction that is opposite of the first flow direction when the moveable member does not contact the seat.

Abstract: A combined disc-type cavitation structure for underwater navigation of an underwater vehicle has an underwater vehicle and a fairing. A plurality of cavitators having sequentially increased outer diameters are sequentially arranged in the fairing. A cavitator receiving groove matched with the cavitator located on the front side is arranged in the center of the front surface of the cavitator located on the rear side in every two adjacent cavitators. The plurality of cavitators can be integrated into a whole by means of the cavitator receiving groove. The cavitator located at the front-most end is a first cavitator, and the remaining cavitators are second cavitators. The first cavitator is connected to the underwater vehicle by means of a buffer. Each second cavitator is respectively connected to the underwater vehicle by means of a driving device configured to axially move the corresponding second cavitator.

Abstract: Wellbore systems include one or more sensing devices configured to sense physical parameters before, during, and/or after fluid injection procedures are performed to inject fluid into a subterranean formation. Seismic vibrations may be induced into the subterranean formation and detected at the injection wellbore or in a remote monitoring wellbore as part of monitoring and evaluation of the fluid injection operations. The one or more sensing devices may also be configured to monitor well production and/or formation conditions in and around a single wellbore and/or in multiple wellbore systems.

Abstract: A system that can include slips configured to selectively engage a tubular string that extends into a wellbore, a slips lifter configured to selectively raise or lower the slips, and a link configured to decouple the slips from the slips lifter when the slips are rotated relative to the slips lifter. A method that can include operations of coupling a slips lifter, via a link, to slips on a rig floor, engaging the slips to a tubular, rotating the slips relative to the slips lifter, and decoupling the slips from the slips lifter by decoupling a first element of the link from a second element of the link in response to rotation of the slips.

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 method for determining and classifying a quality of cement in a wellbore includes receiving input data. The input data is captured by one or more acoustic logging tools in the wellbore. The method also includes generating an image or a curve based upon the input data. The method also includes preprocessing the input data and the image or the curve to produce preprocessed data. The method also includes selecting portions of the preprocessed data for determining and classifying the quality of the cement in the wellbore. The method also includes determining and classifying the quality of the cement in the wellbore based upon the selected portions of the preprocessed data.

Abstract: In one instance, a dual-booster power charge is disclosed for use in a downhole setting tool, wherein the dual-booster power charge has at least a first and a second booster charge disposed within a sleeve and embedded in a main power charge. Each booster charge has one end face that is exposed at the end of the dual-booster power charge. Each booster charge may have a first dimension near the end face that is smaller than a second dimension near the end of the booster charge that is not exposed. In some instances, the booster charges have a charge retention portion and a primary body portion, and a cross sectional diameter of the charge retention portion is larger than a cross sectional dimension of the primary body portion. Other dual-booster power charges and booster charges are disclosed.

Abstract: A device may include a tool housing having an outer surface. A device may include a movable biasing element radially movable relative to the outer surface. A device may include a bore in the outer surface of the tool housing at least partially in a radial direction of the tool housing. A device may include a piston axially fixed to the movable biasing element and movable in the bore. A device may include a pressure ring coupled to the piston and positioned between at least a portion of the piston and an inner wall of the bore.

Abstract: Provided is a lateral locating assembly, a well system, and a method. The lateral locating assembly, in at least one aspect, includes a tubular, as well as a bendable deflection tip coupled to the tubular, the bendable deflection tip configured to move between a straight position and a bent position upon the application of fluid pressure thereto. The lateral locating assembly, according to one or more aspects, further includes one or more production ports coupling an interior of the tubular and an exterior of the tubular, as well as a sliding sleeve positioned about the one or more production ports, the sliding sleeve configured to seal the one or more production ports when in a first position and expose the one or more production ports when in a second position.

Abstract: A drilling fluid system includes: at least one microprocessor device; a container that defines an interior volume; a container inlet that provides access for entry of the at least one microprocessor device into the interior volume of the container; a container outlet that provides egress for passage of the at least one microprocessor device from the interior volume of the container into a drilling fluid conduit of the drilling system; and a dispenser apparatus configured to controllably release the at least one microprocessor device through the container outlet into the drilling fluid conduit of the drilling system. The at least one microprocessor device includes a power source and one or more sensors configured to generate sensor data indicating downhole conditions of a well and to wirelessly transmit the sensor data to a computer at a terranean surface.

Abstract: An embodiment uses a symmetrical elastomeric design with hydraulic pistons on either end (as opposed to a single piston on conventional BOPs) which allows for lower actuation forces, reduced friction, and reduced wear and tear. The lower actuation forces correspond to lower operating pressures which allows the body and housing to be smaller, leading to a smaller footprint.

Abstract: A subsea heat bank for thermally insulating one or more elements of a subsea installation. The heat bank comprises an external casing enclosing an internal space, one or more elements of the subsea installation received in the internal space and arranged such that seawater in the internal space surrounds them, and at least one heat storing member provided in the internal space for increasing the heat-storing capacity of the heat bank. The heat storing member comprising a phase change material (PCM) that has a melting point which is below that of the flow temperature of the well fluid and above the hydrate formation temperature of the well fluid.

Abstract: A method can include rendering a graphical user interface to a display; receiving data; responsive to determining boundary locations for formations in the subsurface environment using the data, automatically rendering the boundary locations in the graphical user interface; responsive to determining extended boundary locations in the subsurface environment for a region beyond an end of the borehole using the boundary locations, automatically rendering the extended boundary locations in the graphical user interface; responsive to determining a target location in the region using the extended boundary locations, automatically rendering the target location in the graphical user interface; and, responsive to generation of a trajectory from an end of the borehole location to the target location, automatically rendering the trajectory in the graphical user interface.

Abstract: A continuous wear measuring device for measuring a wear in a well tool includes a probe configured to wear simultaneously with the well tool, and a control unit electrically connected to the probe and configured to continuously measure a parameter of the probe. The control unit is configured to map a measured value of the parameter to a wear amount of the well tool.

Abstract: A system can include a subsystem and a support device for facilitating torque application of the subsystem during operation. The subsystem can include a hydraulic workover unit that includes hydraulic cylinders. The subsystem can be positioned on a well for facilitating an operation in a wellbore of the well. The support device can be coupled with the subsystem. The support device can include a jaw coupled with the hydraulic cylinder, and the jaw can be arranged with respect to the hydraulic cylinders to facilitate automatic alignment and automatic adjustment of the hydraulic cylinders.

Abstract: Disclosed herein are systems and methods to obtain representative reservoir fluid samples faster. In embodiments, a formation testing tool, which includes a probe and a fluid passageway, is conveyed in a wellbore and the probe is pressed against the wellbore to create a fluidic seal in between the formation and the fluid passageway. The reservoir fluid is then pumped from the formation to the fluid passageway. The probe comprises a rubber disposed on an outer perimeter of the probe and an inflatable barrier disposed between the rubber and a central area of the probe. After reaching a first pre-determined value of drilling fluid contamination, the inflatable barrier of the probe is inflated. Sampling of the reservoir fluid is performed after reaching a second value of drilling fluid contamination in the reservoir fluid pumped from the formation to the fluid passageway.

Abstract: A method can include acquiring resistivity measurements using a downhole tool of a drillstring disposed in a borehole in a subsurface environment; performing a resistivity measurement-based inversion to generate a structural representation of a portion of the subsurface environment that includes an end of the borehole; generating a control instruction using an artificial intelligence framework and the structural representation, where the control instruction is for lengthening the borehole along a current borehole trajectory or a different borehole trajectory; and controlling the drillstring to lengthen the borehole based on the control instruction.

Abstract: A material composition may include one or more polymeric materials. The material composition may also include one or more inorganic particles comprising oxides, carbonates, sulfides, or any combination thereof. Further, the material composition may include one or more metal particles that produce a detectable change in an electrical property or an optical property based on a reaction with at least one of H2O, CO2, or H2S. The one or more inorganic particles and the one or more metal particles may be dispersed within the one or more polymeric materials.

Abstract: A method for performing a hydraulic fracturing operation includes providing a manifold assembly to deliver a fracturing fluid into a well bore. The manifold assembly has a low-pressure section and a high-pressure section. The high-pressure section includes first side inlets at a first side of the manifold assembly, second side inlets at a second side of the manifold assembly. The second side inlets face away from the first side inlets and the second side faces towards fracturing pumps. The method includes fluidly coupling piping assemblies to respective first side inlets. Each piping assembly, at least in part, extends laterally from the first side towards the second side and spans over the high-pressure section. The method includes fluidly coupling high-pressure discharge portions of the fracturing pumps with the piping assemblies such that, high-pressure discharge fluid flows from the fracturing pumps into the high-pressure section via the respective first side inlets.