Abstract: A gun tube for a downhole perforating gun assembly includes a body having a cavity and one or more weights in the cavity. Gravity acts on the weights, which causes the tube body to rotate around its longitudinal axis so the weights are adjacent the lower part of the wellbore in which the gun assembly is positioned when oriented horizontally. This position shape charges in the gun tube in a desired position prior to the shape charges being fired. The gun tube may also include one or more end connectors with electrical contacts having a first, extended position, and a second, contracted position, and/or end connectors that can be assembled by hand without the use of tools.

Abstract: A drilling tip that is attached to a distal end surface of a tool main body of a drilling tool which is rotated around an axis and in which a striking force is applied to a distal end side in a direction of the axis. The drilling tip includes a tip main body in which a base end portion having a columnar shape and a distal end portion protruding from this base end portion to the distal end side are integrally formed. The distal end portion includes a curved convex surface-shaped portion protruding to the distal end side of the tip main body, and a projection portion protruding to the distal end side from a surface of the curved convex surface-shaped portion.

Abstract: An induced earthquake evaluation method for hydraulic fracturing activated faults includes obtaining an induced earthquake evaluation unit, cumulative injection equivalent energy, induced earthquake probability of fault type, induced earthquake probability of fault distance, hydraulic fracturing fluid diffusion capacity in fractured formation, new effective fault stress after fracturing, formation fluid pressure change rate and cumulative released equivalent energy. The probability of induced earthquake by hydraulic fracturing can be obtained. The induced earthquake possibility of each evaluation unit or single well under different stages of hydraulic fracturing, different construction injection methods and production conditions can be quantitatively evaluated. The method provides a quantitative result that can provide data support for optimizing hydraulic fracturing and reducing induced earthquake hazards.

Abstract: A rupture disc configured to fluidly seal a passageway. The rupture disc includes a base extending from a distal surface to a proximal end, and a central portion extending across the proximal end of the base. The central portion traverses a central axis defined by the base. At least one surface of the central portion, such as an outer surface or inner surface, includes a plurality of facets defined by a plurality of seams. The facets may include one or more flat surfaces and/or one or more conical surfaces. A rupture disc system for fluidly sealing a portion of a wellbore includes the rupture disc disposed within and extending across a housing central bore of a housing, with one or more sealing members engaging the rupture disc and an inner surface of the housing central bore to fluidly seal the housing central bore.

Abstract: A well system includes a well platform including a rig floor, a first rig floor robot and a second rig floor robot positioned on the rig floor, wherein the first rig floor robot is configured to guide a lower end of a pipe stand towards a setback position on the rig floor and the second rig floor robot is configured to guide a first pipe joint of the pipe stand into a first mouse hole formed in the rig floor, a mast extending from the rig floor, a racking board coupled to the mast, the racking board configured to secure an upper end of the pipe stand between a pair of finger boards of the racking board, a racking board robot positioned on the racking board and configured to position the upper end of the pipe stand between the pair of finger boards.

Abstract: A rotational continuous circulation system and methods includes a circulation sub having an internal bore extending along a central axis. The circulation sub has an uphole body having a reduced outer diameter along a downhole length of the uphole body. A central valve selectively opens and closes the uphole internal bore. At least one check valve is located within a sidewall of the uphole body to selectively allow fluid to flow into the uphole internal bore through the at least one check valve. A downhole body has an uphole portion circumscribing a downhole portion of the uphole body. A sleeve assembly circumscribes the reduced outer diameter of the uphole body. The uphole body and the downhole body are configured to rotate about the central axis independently from the sleeve assembly. A side-entry port of the sleeve assembly provides a fluid flow path from an exterior of the sleeve assembly to the at least one check valve.

Abstract: Methods and equipment are provided for stimulating recovery of hydrocarbons from a subterranean formation traversed by a wellbore, which employ at least one self-resonating nozzle. Fluid under pressure is supplied to the at least one self-resonating nozzle to create a channel in a surface of the subterranean formation facing the at least one self-resonating nozzle. In embodiments, the equipment can be a downhole tool or completion equipment (such as a liner) that is deployed in the wellbore.

Abstract: A system includes a first wellbore operation controller for controlling a wellbore operation and generating a first broadcast indicating a first data topic desired for controlling the wellbore operation. The system also includes a second wellbore operation controller for generating a data stream associated with a wellbore and for generating a second broadcast indicating a second data topic that promotes the data stream. The system includes a mediator computing device that receives the first broadcast and the second broadcast and determines that the first wellbore operation controller is subscribed to the data stream by comparing the first data topic to the second data topic. In response to determining that the first wellbore operation controller is subscribed to the data stream, the mediator computing device creates a data link between the first wellbore operation controller and the second wellbore operation controller.

Abstract: A method and system for identifying a fluid sample. The method may comprise disposing a fluid sampling tool into a wellbore. The fluid sampling tool may comprise at least one probe configured to fluidly connect the fluid sampling tool to a formation in the wellbore and at least one passageway that passes through the at least one probe and into the fluid sampling tool. The method may further comprise drawing a wellbore fluid as a fluid sample through the at least one probe and through the at least one passageway, obtaining a fluid measurement of the fluid sample, comparing the fluid measurement to a plurality of fingerprints that populate a database, and identifying the fluid sample based at least in part on one of the plurality of fingerprints.

Abstract: The present disclosure provides a method for monitoring pressure of fluid inside a wellhead, wherein the wellhead includes a casing spool defining a channel therein, at least one blind flange, and at least one landing base, the method including: deploying a tube along the channel and inside the casing spool, wherein a plurality of shear pins are distributed on the tube; connecting the tube to the at least one blind flange, wherein the at least one blind flange is connected to a pressure gauge; in response to confirming that the pressure of fluid inside the wellhead is to be determined, shearing the plurality of shear pins against the casing spool from inside the channel; and recording, at the pressure gauge, the pressure of fluid inside an annulus between the tube and the casing spool.

Abstract: A valve for downhole chemical injection control, having a single chemical injection fluid line (2) to feed all the injection points, regardless of the number of zones, exclusively electrically-driven by a single electric cable (3), with embedded sensing electronics (7), which communicate and activate an electric motor (4), coupled to a multi-position sphere (5) for dosing the chemical injection fluid, which, according to the electric motor rotation, is moved, altering its position, to enable the passage of interest to be selected, according to the volume of chemical fluid to be injected, a single turn of the sphere being required to commute all the possible positions, the performance of which is low in power consumption, and for a short period of time, having after its positioning in the desired passage zero consumption to maintain this position.

Abstract: A downhole device and a method of performing an operation in a borehole. The downhole device includes an outer sleeve defining a bore therethrough, an inner sleeve disposed within the bore and axially movable with respect to the outer sleeve between a first position and a second position, the inner sleeve defining a flow passage, and a seat member in the flow passage for seating a ball when the inner sleeve is at the first position. A ball is seated at the seat member. A fluid pressure on the ball moves the inner sleeve from the first position to the second position, moves the seat member radially outward out of the flow passage when the inner sleeve is at the second position, and pushes the ball out of the flow passage.

Abstract: Disclosed are methods, systems, and computer-readable medium to perform operations including: generating, based on production data for a wellbore, (i) a water-oil-ratio with respect to time (WOR) dataset for the wellbore, (ii) a time-derivative dataset (WOR?) of the WOR dataset; generating a WOR log-log plot of the WOR dataset and a WOR? log-log plot of the WOR? dataset; identifying at least one trend in the WOR log-log plot and the WOR? log-log plot; determining, based on the at least one identified trend, a first type of water breakthrough; generating, based on pressure data from a build-up pressure test in the wellbore, a log-log plot of time-derivative pressure data with respect to time (P?); determining, based on the P? log-log plot, a second type of water breakthrough; correlating the first and second type of water breakthrough; and determining, based on the correlation, whether to perform a water treatment for the wellbore.

Abstract: A system and method are disclosed for centralized monitoring and control of a hydraulic fracturing operation. The system includes an electric powered fracturing fleet and a centralized control unit coupled to the electric powered fracturing fleet. The electric powered fracturing fleet can include a combination of one or more of: electric powered pumps, turbine generators, blenders, sand silos, chemical storage units, conveyor belts, manifold trailers, hydration units, variable frequency drives, switchgear, transformers, and compressors. The centralized control unit can be configured to monitor and/or control one or more operating characteristics of the electric powered fracturing fleet.

Abstract: A system can include one or more processors; memory; a data interface that receives data; a control interface that transmits control signals for control of pumps of a hydraulic fracturing operation; and one or more components that can include one or more of a modeling component that predicts pressure in a well fluidly coupled to at least one of the pumps, a pumping rate adjustment component that generates a pumping rate control signal for transmission via the control interface, a capacity component that estimates a real-time pumping capacity for each individual pump, and a control component that, for a target pumping rate for the pumps during the hydraulic fracturing operation, generates at least one of engine throttle and transmission gear settings for each of the individual pumps using an estimated real-time pumping capacity for each individual pump where the settings are transmissible via the control interface.

Abstract: A method includes performing a downhole operation in a borehole; capturing, during the downhole operation, downhole particles and drilling mud at the surface from the borehole into a screen of at least one shaker; shaking the screen to emit vibrations to separate the downhole particles from the drilling mud; defining a vibration limit for a normal operating condition of the at least one shaker; setting a vibration fault threshold based on the vibration limit for the normal operating condition; monitoring, using at least one sensor, the vibrations over time; and determining there is a fault condition for the shaker, in response to the vibrations exceeding the vibration fault threshold.

Abstract: A composite product has a body of polycrystalline diamond (PCD) material having a PCD proximal end and a PCD distal end, an electronic device including an electronic component, and a connection portion joining the electronic device to the body at the PCD distal end, and comprising metallic join material having a liquidus temperature of 600° C. to 950° C. at atmospheric pressure. At least one of the electronic device and the body includes an electrically insulating portion between the electronic component and the PCD proximal boundary establishing an electrical open circuit condition between the electronic component and the PCD proximal boundary. A method of making the composite product is also disclosed.

Abstract: A method of controlling a pumping stage of a fracturing fleet at a wellsite with a set of electric frac pumps to deliver fracturing fluids into a target formation at a steady pressure value. An global control process on a computer system communicatively connected to the plurality of pumping units can communicate a unit setpoint to each pumping unit, monitor the sensor measurements, compare the periodic datasets to a target pressure, and modify the fluid output of the pump units to achieve the target pressure during the pumping operation. The global control process can direct at least one pumping unit to deliver a fracturing treatment at a pressure higher or lower than the target pressure in response to changing wellbore environment pressures.

Abstract: Systems and methods for predicting a breakdown pressure of a formation and fracturing the formation account for filter cake effects. The systems and methods measure a time-dependent permeability and a time-dependent thickness of a filter cake formed by a first drilling mud. The systems and methods determine a time-dependent permeability model and a time-dependent thickness model of the filter cake. The systems and methods select a breakdown pressure model based on (i) the time-dependent thickness of the filter cake, (ii) the time-dependent permeability of the filter cake, and (iii) the permeability of the formation. The systems and methods use the selected breakdown pressure model to predict the breakdown pressure of the formation and fracture the formation using a drilling fluid having a mud weight associated with the predicted breakdown pressure of the formation.

Abstract: Some embodiments may be directed to a drilling tool for drilling in a formation. This drilling tool may include an optical fiber having a laser input end and a laser output end and a laser source optically connected to the laser input end. Further, the drilling tool may include an activating agent conduit having an activating agent inlet and an activating agent outlet and an activating agent source connected to the activating agent inlet that supplies an activating agent. Finally, the drilling tool may include a drill head. In some embodiments, the drill head may include a nozzle connected to the activating agent outlet that discharges the activating agent on an area of the formation, and a laser head optically connected to the laser output end and arranged to lase at least a portion of the area of the formation having the activating agent.