Abstract: Provided, in one aspect, is a cementing apparatus. The cementing apparatus, in one embodiment comprising a housing; a fixed member coupled with the housing, the fixed member having at least one fixed member fluid opening therein; and a moving member positioned downhole of the fixed member and movable between a circulating position and a cemented position, the moving member having at least one moving member fluid opening therein, the at least one moving member fluid opening linearly offset from the at least one fixed member fluid opening.

Abstract: Systems and methods using: a membrane unit to treat fluids recovered from an oil and gas well are provided. The membrane unit may include a membrane having a porous substrate at. least partially coated with graphene oxide, making the membrane hydrophilic. The membrane separates water from other components within a fluid stream. The membrane unit may include an inlet to receive a fluid stream into the membrane unit. The fluid stream may be pretreated prior to reaching the membrane unit The membrane unit may also include a first outlet in fluid communication with one side of the membrane and a second outlet in fluid communication with the opposite side of the membrane.

Abstract: A sealing assembly for use in a wellbore tool includes thermoplastic materials arranged in a lattice structure to provide a bulk elasticity on the order of elastomeric materials. The lattice structure permits an energizing element of the sealing assembly to deform sufficiently in the elastic range of the thermoplastic materials to provide repeatable sealing capabilities. The lattice structure may be constructed by additive manufacturing processes to include voids therein, which allow the thermoplastic members of the lattice to flex and bend. The energizing element may thereby exhibit a greater elasticity in bulk than the elasticity of the thermoplastic materials themselves. The lattice structure may be enclosed in an outer cover constructed of a polymeric, elastomeric or other material to facilitate the interaction between the seal assembly and the corresponding sealing surfaces of a downhole wellbore tool.

Abstract: Fluid holdups within a downhole sampling tool are identified by comparing high- and low-resolution measurements of fluid samples.

Abstract: A drilling system for drilling a well. The drilling system may include a drillstring, a gas detector, and a computer system. The drillstring may include a downhole motor operable to rotate a drill bit and the downhole motor may include a stator and a rotor, at least one of the stator or the rotor comprising an elastomer compound. The gas detector may be operable to detect a gas indicative of deterioration of the elastomer compound. The computer system may be programmed to generate an indication based on the detection of the gas indicative of the deterioration by the gas detector.

Abstract: A downhole tool and method of utilizing the downhole tool to make measurements in a wellbore formed in a formation and having different wellbore diameters. The downhole tool generally includes a tool body defined along a longitudinal central axis and having an internal passage extending longitudinally therethrough and an external pocket extending therealong; a sensor module having a sensor and being deployed within the external pocket; a spacer deployed in the external pocket, the spacer positioned between the sensor module and the tool body; and a clamp attached to the tool body, the clamp overlaying both the sensor module and the spacer to confine the sensor module within the external pocket. The spacer may have an inner concave surface engaging the sensor module and an outer convex surface seating in the external pocket.

Abstract: Provided is a float for use with a fluid flow control device, a fluid flow control device, a method for manufacturing a float, and a well system. The float, in one aspect, includes a fluid tight enclosure. The float, according to this aspect, further includes density specific material located within the fluid tight enclosure, the fluid tight enclosure and the density specific material creating a net density for the float that is between a first density of a desired fluid and a second density of an undesired fluid, such that the float may control fluid flow through a flow control device when encountering the desired fluid or the undesired fluid.

Abstract: Provided, in one aspect, is a method for forming a well system. The method, in one aspect, includes forming a wellbore within a subterranean formation, and positioning an anchoring subassembly within the wellbore. The method, according to this aspect, further includes washing over at least a portion of the anchoring subassembly with a washover assembly, and then removing the washed over anchoring subassembly from the wellbore.

Abstract: The disclosure presents systems and methods for hot swapping pumps at a wellsite while minimizing the impact to the pumping operations. As one pump is swapped out, such as for maintenance, the remaining pumps in the set of pumps at the wellsite can continue pumping operations. In some aspects, the swapping of pumps can be performed by a user using a protection barrier to isolate the pump location where the pumps will be swapped. In some aspects, one or more of the steps to swap pumps can be performed through automation thereby minimizing danger to a user. In some aspects, the pump being located at the pump system can be primed and pressure tested prior to be located to improve the time to enable the pump for pumping operations.

Abstract: The disclosure provides a solution for monitoring stick-slip vibrations without using any surface torque measurements. Instead, the disclosure provides a method to monitor stick-slip vibrations based on rotational speed. A stick-slip monitor, a top drive controller and a method of operating a drill string are provided herein that use rotational speed for monitoring stick-slip vibrations. In one example, the method of operating a drill string includes: (1) performing a frequency domain analysis of an RPM signal associated with a top drive that is used to rotate a drill string, and (2) determining a presence of torsional oscillations of the drill string based on the frequency domain analysis of the RPM signal.

Abstract: Provided is a valve assembly and method for opening and closing thereof. The valve assembly, in one aspect, includes a valve body having inlet and outlet flow passageways connected by a valve chamber, and a ball valve member having a bore there through creating a ball/bore interface, the ball valve member located in the valve chamber for selective rotation between valve open and valve closed positions to control flow through the valve assembly. The valve assembly, according to this aspect, includes a linear actuation member slideable to engage proximate the ball/bore interface to assist in moving the ball valve member to the valve closed position.

Abstract: A pigging tool may include a housing positionable in a pipeline. The housing may define a bypass channel that extends along an axis that is nonparallel to a longitudinal axis of the housing. An energy generation device can be positioned in the bypass channel of the housing such that fluid is receivable by the energy generation device to generate energy for the pigging tool. Further, an energy storage device may store energy generated from the energy generation device. The energy storage device may provide the pigging tool with energy to perform one or more operations in the pipeline.

Abstract: A method of designing a cement job may include: (a) selecting a cement job plan comprising: cement placement variables, wellbore construction variables, and subterranean formation properties; (b) calculating a predicted hydraulic pressure (Phydraulic) of the cement job plan using a physics based hydraulic model; (c) calculating a pressure differential (?P) of the cement job plan using a data driven hydraulic model; (d) calculating a predicted observed surface pressure (Pobserved) from the pressure differential (?P) and a predicted hydraulic pressure (Phydraulic); (e) comparing the predicted observed surface pressure (Pobserved) to a surface pressure requirement window, wherein steps (a)-(e) are repeated if the predicted observed surface pressure (Pobserved) is within the surface pressure requirement window, wherein each repeated step of selecting comprises selecting at least one different cement placement variables than previously selected, or step (f) is performed if the if the predicted observed surface pre

Abstract: A downhole fluid sampling tool may include: a tool body; a flow port disposed on the tool body; a sample chamber disposed within the tool body and fluidly coupled to the flow port; a pump disposed within the tool body, wherein the pump is configured to pump a fluid through the flow port into the sample chamber; a filter disposed on an inlet of the flow port, wherein the filter is configured to filter the fluid entering the flow port; and a removable filter cover configured to prevent fluid contact with the filter.

Abstract: The disclosure provides a formation fluid pumping method and pump, and a wellbore system that in one example includes wellbore surface equipment connected to a downhole tool including a formation fluid container having a fluid input port and a fluid output port, and a moveable piston inside the formation fluid container having two fluid chambers positioned to alternately pump a quantity of formation fluid in the formation fluid container from the fluid input port to the fluid output port. The wellbore system further includes a mechanical piston actuator having a rotary portion attached to the formation fluid container and a linear portion attached to the moveable piston, and a brushless direct current motor coupled to the rotary portion of the mechanical piston actuator and controlled to alternately rotate the rotary portion of the mechanical piston actuator in opposite directions to pump the quantity of formation fluid.

Abstract: Systems and methods are disclosed for identifying one or more vibration mechanisms or other mechanism associated with tool failure. In one example, a machine learning data system comprises a data pre-processing module, a machine learning training module, and a predictive module. The pre-processing module analyzes dynamic sensor input to identify one or more vibration mechanisms associated with a downhole tool. The machine learning training module identifies a correlation between dynamic sensor data and failure data for a plurality of downhole tools. The predictive module correlates the one or more vibration mechanism with tool failure or performance.

Abstract: A linear escapement mechanism is provided for actuating a downhole tool in a controlled and predictable manner, such as in response to a certain number of pressure cycles. In an example, the actuator includes an escapement sleeve axially moveable with respect to an actuator housing. The escapement sleeve has a plurality of axially-arranged escapement teeth. A rocker secured within the actuator housing has opposing first and second pallets. An operating sleeve is reciprocable to rock the rocker back and forth to alternately move the opposing first and second pallets into engagement with the escapement sleeve as the escapement sleeve advances axially in an actuating direction.

Abstract: The present disclosure provides methods that use polymerized alkali silicate gels. An example method comprises: introducing a polymerized alkali silicate gel into a subterranean formation containing a fault, wherein the polymerized alkali silicate gel is introduced the subterranean formation such that at least a leading edge of polymerized alkali silicate gel is placed in the fault or within about 10 miles from the fault.

Abstract: Systems and methods of the present disclosure relate to actuator assemblies for downhole tools. An actuator assembly comprises a motor, a spring and a hammer. The spring is adjacent to the hammer, and the hammer operable to compress the spring. The spring is operable to expand. The assembly also includes an anvil adjacent to the hammer. The anvil is operable to move a portion of the downhole tool.

Abstract: The disclosed embodiments include methods to monitor expansion of a metallic sealant deployed in a wellbore, methods to monitor downhole fluid displacement, and downhole metallic sealant measurement systems. The method to monitor expansion of a downhole metallic sealant includes deploying a metallic sealant deployed along a section of a wellbore. The method also includes exposing the metallic sealant to a reacting fluid to initiate a galvanic reaction. The method further includes measuring a change in temperature caused by the galvanic reaction. The method further includes determining an amount of expansion of the metallic sealant based on the change in the temperature.