Abstract: A system and downhole tool comprising an ultrasonic transducer with a piezoelectric material embedded in a backing and a method of determining a parameter using the ultrasonic transducer. A self-noise of the transducer can be reduced by the piezoelectric material being at least partially embedded in the backing. The ultrasonic transducer can include an encapsulating material that encapsulates the backing.

Abstract: Systems and methods for noise cancellation in electromagnetic telemetry systems. A method for noise cancellation in electromagnetic telemetry may include: disposing an electromagnetic tool in a lateral section of a wellbore, wherein the electromagnetic tool comprises a transmitter; positioning a first counter electrode at a surface of the Earth; positioning a second counter electrode at the surface on an opposite side of the wellbore from the lateral section; transmitting a signal from the electromagnetic tool; measuring a first electromagnetic field property using the first counter electrode to obtain a received voltage; measuring a second electromagnetic field property using the second counter electrode to obtain a noise voltage; and removing noise from received voltage using the noise voltage.

Abstract: A method of pressure testing a well tool can include applying positive or negative pressure to an internal chamber of the well tool, or determining a reference pressure, and monitoring the pressure in the internal chamber using a pressure sensor in the internal chamber. Another method can include applying pressure to an internal chamber of a well tool at a surface location, thereby creating a pressure differential in one direction across a seal, and installing the well tool in a well, thereby creating another pressure differential in a possibly opposite direction across the seal. A well system can include a well tool including an internal chamber, and a pressure sensor disposed in the chamber, whereby the pressure sensor detects pressure within the chamber.

Abstract: Methods and systems for a remote control flow path system in a wellbore. In one embodiment, the system comprises a plurality of transceivers spaced in the wellbore; a telemetry module operable to wirelessly receive control signals from a surface location by way of the plurality of transceivers and to wireless transmit signals to the surface location by way of the plurality of transceivers; a control module comprising a controller, a pump, and a reservoir of hydraulic fluid; a plurality of valves; and a plurality of control lines for the hydraulic fluid, wherein the plurality of control lines are disposed between the pump and the plurality of valves; wherein the control module is operable to hydraulically actuate one or more of the valves to open or closed positions in response to the control signals from the surface location to create one or more flow paths in the wellbore.

Abstract: A system to determine a contamination level of a formation fluid, the system including a formation tester tool to be positioned in a borehole, wherein the borehole has a mixture of the formation fluid and a drilling fluid and the formation tester tool includes a sensor to detect time series measurements from a plurality of sensor channels. The system includes a processor to dimensionally reduce the time series measurements to generate a set of reduced measurement scores in a multi-dimensional measurement space and determine an end member in the multi-dimensional measurement space based on the set of reduced measurement scores, wherein the end member comprises a position in the multi-dimensional measurement space that corresponds with a predetermined fluid concentration. The processor also determines the contamination level of the formation fluid at a time point based the set of reduced measurement scores and the end member.

Abstract: Systems and methods for optimized geosteering include creating a parameter matrix, which comprises a formation property for each pair of true vertical depth (TVD) coordinates from a geological model and measured depth (MD) coordinates from a predefined well trajectory; updating the parameter matrix by replacing the TVD coordinates and the MD coordinates for each parameter entry in the parameter matrix with the TVD coordinates and the MD coordinates for an actual well trajectory; and compiling a distance to bed boundary (DTBB) array and one or more other logging while drilling (LWD) arrays using corresponding measurements at the MD coordinates of the actual well trajectory; and calculating a value for each parameter entry in the updated parameter matrix, which is a sum of a geology array, the DTBB array and the one or more other LWD arrays that are each multiplied by respectively assigned or calculated weights.

Abstract: An apparatus for controlling fluid flow into a well includes an outer tubular member and an inner tubular member. The outer tubular member includes a screen configured to enable fluid flow therethrough between an exterior and an interior of the outer tubular member. The inner tubular member is configured to be positionable within the outer tubular member. The inner tubular member is a remotely activated flow control device configured to control fluid flow between an exterior and an interior of the inner tubular member.

Abstract: A method and system for ranging between two cased wellbores. A method may comprise disposing a first downhole tool on a first conveyance line in a first cased wellbore, disposing a second downhole tool on a second conveyance line in a second cased wellbore, broadcasting an electromagnetic field from the transmitter, recording the electromagnetic field with the receiver, transmitting the recording to an information handling system, and calculating relative position between the first cased wellbore and the second cased wellbore with the information handling system. An electromagnetic ranging system for ranging between two cased wellbores may comprise a first downhole tool, a first conveyance line, a second downhole tool, a second conveyance line, and an information handling system configured for exciting the transmitter.

Abstract: A screen assembly for a production tool, the screen assembly including a tubular member defining an interior passageway; and a plurality of flow paths defined by the tubular member, the plurality of flow paths forming a screen portion that permits fluid flow through the screen portion and into the interior passageway; wherein the plurality of flow paths form a fractal flow network.

Abstract: This disclosure relates generally to downhole tools and, more particularly, embodiments related to incorporation of a pumpdown relief valve into a downhole tool that is responsive to changes in differential fluid pressure along a downhole tool. Disclosed is a system for pumpdown regulation in a wellbore. The system may include a downhole tool having a tool body with a tool head that is attachable to a line, the line being attached to a point at a surface of the wellbore. The system may further include a pumpdown relief valve coupled to the tool body that is operable to allow fluid to bypass the downhole tool in direct response to a differential fluid pressure across a length of the downhole tool.

Abstract: A downhole tool for use within a borehole. The downhole tool may include a body including a port that allows fluid flow between a bore of the downhole tool and an area outside of the body and a sleeve slidable from a run-in position to an actuated position. Either the run-in position or the actuated position may prevent flow through the port. Additionally, at least one of an end of the sleeve or a surface of the body may be coated in solder particles having an outer shell and a liquid metal core. Further, the solder particles may be rupturable when the sleeve is shifted to the actuated position into contact with the surface to expose the liquid metal such that the liquid metal solidifies and forms a bond to retain the sleeve in the actuated position.

Abstract: The present disclosure relates generally to equipment utilized and operations performed in conjunction with a subterranean well and, more particularly, to an improved liner hanger system. A downhole expandable liner hanger positionable in a subterranean wellbore may comprise an expansion element. The expansion element may comprise a tubular body. The expansion element may comprise one or more annular seals bonded to the tubular body. The expansion element may comprise a first spike extending from the tubular body. The expansion element may comprise a second spike extending from the tubular body. The downhole expandable liner hanger may further comprise a first slip ring, wherein the first slip ring is disposed around the tubular body of the expansion element between the first spike and the second spike, wherein the first slip ring is configured to expand radially as the expansion element expands.

Abstract: A directional drilling device for drilling a borehole having a borehole wall, the device including an outer housing and a driveshaft selectively rotatable with respect to the housing and including an axial flow bore and a through port formed in the driveshaft wall. The device also includes one or more borehole engagement members rotatable with and radially moveable with respect to the outer housing toward engagement with the borehole wall to urge the directional drilling device in a radial direction with respect to the borehole. The device further includes a mud pressure actuation system. The mud pressure actuation system controls fluid flow through the through port to control hydraulic pressure on a piston device and thus movement of the borehole engagement members into engagement with the borehole wall to maintain a rotational position of the outer housing and the corresponding radial direction in which the device is being urged.

Abstract: A method and system for modeling a fracture geometry. The method may comprise taking one or more pressure measurements from an offset wellbore, identifying a pressure trend of the offset wellbore, and comparing the one or more pressure measurements to the pressure trend to identify a poro-elastic trend. The method may further comprise creating a poro-elastic model of a target wellbore from the poro-elastic trend, identifying the fracture geometry of a fracture in the target wellbore from at least the poro-elastic trend, and comparing the fracture geometry to a target fracture geometry. The system may comprise a pressure measurement device disposed in an offset wellbore, one or more pieces of equipment configured for a fracture operation and connected to a target wellbore, and an information handling system.

Abstract: A system for and method of use with a downhole tool that includes a tubular with a fluid flow path therethrough for flowing a fluid and a housing coupleable to a downhole portion of the tubular. A fluid-driven motor assembly is included and has a drive shaft rotatable to output rotational drive forces. An electric generator is coupled to the drive shaft to convert the rotational drive forces into electrical power. There is also an electric motor electrically coupled to the electric generator to convert electrical output of the electric generator into a rotational drive force to control the downhole tool. A controller is electrically coupled to the electric motor and the electric generator to conduct electrical power output from the electric motor to the electric generator and dissipate excess energy produced by the electric motor to the fluid-driven motor assembly as hydraulic energy.

Abstract: A centralizing perforating gun for perforating a tubular in a wellbore include a gun housing, perforating charges positioned within the gun housing and detonatable to perforate the tubular, and a centralizing system. The centralizing system includes an extendable member configured to move between a retracted position and an extended position. The extendable member is configured to engage a surface of the tubular in the extended position, thereby biasing the centralizing perforating gun away from the surface of the tubular.

Abstract: A method for determining discharge area in hydraulic stimulation operations is provided that includes obtaining one or more treatment data inputs from a well system, and determining a discharge area by applying the one or more treatment data inputs to a function that determines discharge area in terms of volumetric flow rate of the fracturing fluid, wherein the discharge area is a total area of all downhole exits through which the fracturing fluid exits a wellbore into a subterranean formation.

Abstract: A method evaluating borehole subsurface geologies can include receiving a total response signal by a sensor array disposed in a borehole, the response signal represents a pressure wave propagating in the borehole. A secondary signal can be extracted from the total response signal and a depth location for at least one secondary source that corresponds to the secondary signal is determined. An estimated reflectivity response for the secondary signal as a function of frequency is determined and the estimated reflectivity response is inverted to determine the secondary source includes at least one of a potential fracture or a potential washout. The at least one of a fracture conductivity or a washout volume for the secondary source is compared to one or more borehole images corresponding to the depth location of the secondary source to determine the potential fracture is an actual fracture or the potential washout is an actual washout.

Abstract: This disclosure provides a dissolvable sealing joint system that can be used in an improved method of sealing a multi-lateral well junction. The sealing joint system is comprised of a dissolvable junction subassembly that can be easily removed after a sealing operation is conducted. A tapered end of the dissolvable junction subassembly is inserted in a liner of a secondary wellbore, and a seal located about the tapered end is sealed against the top of the liner and a no-go shoulder of dissolvable junction subassembly. Once a seal is established, an isolation fluid is pumped into the junction area via a fluid port located in the dissolvable junction subassembly. A method of isolating a wellbore junction is also presented.

Abstract: A method and system for determining properties of a pipe string using multi-channel induction measurements. The method may comprise disposing a multi-channel induction tool in a cased hole, obtaining a multi-channel measurement, forming a log from the multi-channel measurement, extracting at least one abnormality that corresponds to known metal thickness, performing a search to find a set of pipe material properties that minimize a mismatch between the abnormality and a simulated response, and inverting the log to estimate the set of pipe material properties at one or more depth points using the set of pipe material properties. The system may comprise a multi-channel induction tool. The multi-channel induction tool may comprise at least one transmitter, at least one receiver, and an information handling system.