Abstract: A technique facilitates patching of a tubing (42), e.g. casing (36), in a downhole environment (32). The technique employs a patching system comprising a plurality of expansion rings (48). The expansion rings (48) are moved downhole to a patch zone (38) along the tubing (34). Once in a desired position at the patch zone, the expansion rings (48) are expanded into engagement with an inner surface of the tubing. For example, the expansion rings may comprise seal elements (52) and/or anchor elements which are expanded into engagement with the inside surface. The patching system further comprises a patch (68) which may have a tubular shape. The patch is radially expanded in a manner which maintains a sealing engagement with the plurality of expansion rings (48) to create a sealed patch across a desired region in the patch zone.

Abstract: Apparatus and methods for optimizing a stick-slip algorithm for controlling a driver of a drill string. A method may include commencing operation of a control system for controlling the driver. The control system may have a processor and a memory storing a computer program code, which may include the stick-slip algorithm. The operating control system may receive a plurality of different numerical parameters, and for each of the different numerical parameters, incorporate the numerical parameter into the stick-slip algorithm and execute the stick-slip algorithm to determine a control command that causes the driver to rotate the drill string to perform drilling operations while reducing amplitude of rotational waves travelling along the drill string.

Abstract: Drilling fluid compositions include an emulsifier having a generic structure A, structure B, or a combination thereof. Structure A includes an amide (e.g., amic acid group) and structure B includes a cyclic imide. The emulsifier of the emulsifier system is formed by reacting a fatty oil amine (e.g., oleyl amine), with a cyclic anhydride (e.g., succinic anhydride) in the absence of diluent or in a diluent that does not react with the starting materials. The reaction takes place via application of a stepwise increase in temperature. An emulsifier based on structure A is formed when the reaction temperature is maintained at 50 to 100° C. for 1 to 3 hours. A further increase in reaction temperature (e.g., up to 200° C.) can include water elimination which results predominately in the formation of a molecule represented by structure B.

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 downhole assembly includes a bit and a cutting tool uphole of the bit. The cutting tool has one or more expandable cutter arms. The one or more expandable cutter arms include at least one stabilizer portion having a radial position that is about the same as a gauge of the bit when the one or more expandable cutter arms are in an expanded position. A spline on the cutter arms are used by a cutting tool to move the cutter arms.

Abstract: A downhole tool includes a tool body and an actuator coupled to and selectively extendible relative to the tool body. The actuator has a working face that contacts a downhole formation, and which includes an upper portion and a lower portion. The lower portion has a tapered surface that is directed radially inwardly and axially downwardly relative to the first portion, with at least a portion of the tapered surface including an ultrahard material having a different coefficient of friction as compared to a first material of the upper portion.

Abstract: A cutting element may include a substrate; and an ultrahard layer on the substrate, the substrate and the ultrahard layer defining a non-planar working surface of the cutting element such that the ultrahard layer forms a cutting portion and the substrate is at least laterally adjacent to the ultrahard layer. Another cutting element includes a pointed region having a side surface extending from the pointed region outer perimeter to a peak. An ultrahard material body forms a portion of the pointed region including the peak, and a base region extends a depth from the pointed region outer perimeter. The ultrahard material body has a height to width aspect ratio with the height and width measured between two points of the body having the greatest distance apart along a dimension parallel with a longitudinal axis (i.e., height) along a dimension perpendicular to the longitudinal axis (i.e., width).

Abstract: Aspects of the present disclosure relate to a valve control system. The valve control system may include a transmitter and a plurality of valve controllers that each have a receiver. Each valve controller of the plurality of valve controllers is configured to control a respective valve of a plurality of valves. In some embodiments, the transmitter may transmit an electromagnetic signal that includes an encoded message to be decoded by a processor of each valve controller of the plurality of valve controllers. In some examples, the encoded message may include a synchronization message, an instruction message, an error correction message, an encryption message, or any combination thereof that enables the plurality of valve controllers to adjust the plurality of valves to respective target positions.

Abstract: Using machine learning for sedimentary facies prediction by using one or more logs acquired in a borehole. This includes performing a petrophysical clustering of borehole depths wherein the depths of the borehole are gathered into clusters based on similarities in the one or more logs. Also performed is a log inclusion optimization, including a selection of one or more parameters of the petrophysical clustering, wherein the one or more parameters include a number and/or type of considered logs among the one or more logs and/or a clustering method. Also performed is a classification of the clusters into core depositional facies using one or more predetermined rules.

Abstract: A technique facilitates fluid analysis in situ at a downhole location. According to an embodiment, a sample of fluid, e.g. oil, is obtained from a reservoir at the downhole location in a borehole. A downhole sampling system is used to determine contamination of the sample of fluid and to determine other selected characteristics of the sample. The data obtained is then processed to determine a true phase transition property of a native fluid in the sample of fluid. The sample analysis may be performed at selected stations along the borehole during, for example, a well cleanup operation. The immediate analysis of fluid samples downhole facilitates rapid development of an understanding of fluid characteristics in the reservoir, thus enabling an improved oil recovery strategy.

Abstract: A device for handling a tubular member includes a gripping assembly configured to grip the tubular member. The gripping assembly includes a first arm and a second arm, which are configured to pivot between an open position and a closed position. The device also includes a first plurality of rollers coupled to the first arm and a second plurality of rollers coupled to the second arm. The first plurality of rollers and the second plurality of rollers are configured to grip the tubular member at different locations around a circumference of the tubular member when the first arm and the second arm are in the closed position, and the first plurality of rollers and the second plurality of rollers are configured to rotate the tubular member while the tubular member is being gripped by the gripping assembly.

Abstract: A method of performing a wellbore operation may include circulating an oil-based wellbore fluid having a conductive material therein within a wellbore, the oil-based wellbore fluid having a conductivity of at most 0.02 S/m when measured at 20 kHz; and forming a filtercake having a conductivity at least two orders of magnitude higher than the oil-based wellbore fluid on at least a portion of a wall of the wellbore.

Abstract: A method for making natural gamma ray measurements of a subterranean formation includes causing a natural gamma ray sensor on an LWD tool to acquire a spectral gamma ray measurement while a neutron source emits neutrons. The measurements are evaluated to compute first and second drilling fluid activation corrections using corresponding first and second correction methodologies. The first and second corrections are processed to compute a third drilling fluid activation correction which is applied to the gamma ray measurements to compute a corrected total natural gamma ray measurement.

Abstract: A method can include accessing volumetric data from a data store, where the volumetric data correspond to a region; generating structured shape information for the region using at least a portion of the volumetric data; and, in response to a command from a client device, transmitting to the client device, via a network interface, a visualization data stream generated using at least a portion of the structured shape information.

Abstract: A stabilizer can include an outer collar, an inner sleeve, and a locking mechanism. The locking mechanism is changeable between a first mode in which the outer collar is rotationally fixed to the inner sleeve and a second mode in which the outer collar is rotationally isolated relative to the inner sleeve. The stabilizer may include an active or passive system for changing modes. An example passive device may include a magnetic clutch where the detected force overcomes magnetic forces to change mode. The stabilizer can be used to mitigate whirl on a rotating device by switching the rotating device between a rotating mode and a non-rotating mode. In the rotating mode, outer collar may rotate with the inner sleeve. In the non-rotating mode, the outer collar may be rotationally isolated from the inner sleeve.

Abstract: Thermally induced graphene sensing circuitry and methods for producing circuits from such thermally induced circuits are presented in conjunction with applications to hydrocarbon exploration and production, and related subterranean activities. The thermally induced graphene circuity advantageously brings electrically interconnections otherwise absent on oilfield service tools, enabling components and tools to become smart.

Abstract: A computer-implemented method including receiving a steering command identifying a tool face orientation in which the steering command is expected to produce an intended steering response of an intended drilling trajectory. The method further includes receiving an actual steering response result of the steering command in which the actual steering response result identifies an actual drilling trajectory. The method further includes storing a dataset comparing the actual steering response result in relation to the intended steering response, determining an uncertainty level of the tool face orientation based on the stored dataset, and outputting a visual representation of steering response with the uncertainty level.

Abstract: A system and method for controlling a pump in a drilling system, of which the method includes determining a plurality of baseline behaviors for one or more valves of the pump, determining a plurality of in-use behaviors for the one or more valves of the pump. Each of the plurality of in-use behaviors are determined based on one or more measurements from one or more sensors. The method also includes comparing the in-use behaviors and the baseline behaviors, and forecasting, based on the comparison of the in-use behaviors and the baseline behaviors, a remaining useful life of the at least one of the one or more valves.

Abstract: A technique facilitates actuation of a downhole device, such as an isolation valve. According to an embodiment, the downhole device may be in the form of an isolation valve member, e.g. a ball valve element, actuated between positions by a mechanical section which may comprise a shifting linkage. Actuation of the mechanical section, and thus actuation of the isolation valve member, is achieved by a trip saver section controlled according to a pressure signature which may be applied from a suitable location, e.g. from the surface. The trip saver section comprises a housing having an internal actuation piston coupled with the mechanical section. The trip saver section further comprises a pilot piston and a plurality of chambers formed in a wall of the housing and arranged to enable shifting of the actuation piston in response to a predetermined series of pressure pulses or other suitable pressure signature.

Abstract: Systems and methods for using high rate telemetry to improve drilling operations. A method may include performing drilling operations with a wired drill pipe (WDP) string in an oil and/or gas well. The drilling operations may include pumping drilling fluid to a mud motor of the WDP string through an internal passage of the WDP string and vertically moving the WDP string via a drawworks while controlling the drawworks to change speed of the WDP string based on downhole data received by wellsite surface equipment via electrical conductors integral to WDP of the WDP string. The received downhole data may include downhole pressure data that is generated downhole by a pressure sensor and is indicative of pressure of the drilling fluid in the internal passage.