Abstract: A drill rod guard having a feed shaft assembly that supports a feed shell for receiving a drill rod. First and second shafts are respectively pivotally coupled to opposed sides of the feed shaft assembly. A plurality of guard elements are operatively coupled to the first and second shafts, and opposed guard elements are selectively engageable with one another. Upon engagement between the opposed guard elements, the guard elements cooperate with the feed shell and/or the feed shaft assembly to substantially enclose the portion of the drill rod within the feed shell to thereby prevent contact with the drill rod.

Abstract: A downhole actuating apparatus (10) comprising a body (12), an object (14) provided on the body, and a sealing arrangement (30) provided on the body and axially spaced from the object. In use, the apparatus (10) is deployed downhole until the object (14) engages an obstacle (44). The sealing arrangement is configured to provide protection for the object during deployment of the apparatus and/or while the apparatus is engaged with the obstacle.

Abstract: A system including a rotary isobaric pressure exchanger (IPX) configured to exchange pressures between a first fluid and a second fluid, and a motor system coupled to the hydraulic energy transfer system and configured to power the hydraulic energy transfer system.

Abstract: A system, method and a computer program product may be provided for characterizing natural resource subsurface attributes and compositions. The system prescribes alterations of one or more controls of a natural resource. The system applies the altered controls to the natural resource wells. The system collects measurement data of the natural resource wells that responds to the applied altered controls. The system determines, based on the collected measurement data, the natural resource subsurface attributes and compositions that pertain to the natural resource.

Abstract: Systems and methods for filtering a production stream downhole that involves creating a basepipe annulus and a casing annulus and forcing the production stream through a filter between the casing annulus and the basepipe annulus before combining the production stream with a previously filtered production stream. Other systems and methods are disclosed.

Abstract: Techniques for controlling flow of a wellbore fluid include positioning a plurality of inflow control assemblies on a pipe joint in a wellbore, the pipe joint including a proximal end engageable with a first downhole tool and a distal end engageable with a second downhole tool; receiving a flow of a wellbore fluid from a subterranean zone to an inlet of at least one inflow control device (ICD), the at least one ICD mounted in each of the plurality of inflow control assemblies, the flow at a velocity that is less than the transport velocity of fines in the wellbore fluid; and transmitting the flow of the wellbore fluid to the pipe joint from the ICDs to an interior of the pipe joint.

Abstract: A deployment assembly for expanding a liner string in a wellbore includes: a tubular mandrel having a bore therethrough; an expander linked to the mandrel and operable between an extended position and a retracted position; an extension tool disposed along the mandrel and operable to extend the expander; and a retraction tool disposed along the mandrel. The retraction tool has: an upper piston in fluid communication with the mandrel bore and operable to retract the expander; a lower piston in fluid communication with the mandrel bore and operable to balance the upper piston; a valve disposed between the pistons for isolating the lower piston from the upper piston in a closed position; and an electronics package linked to the valve for opening and closing the valve in response to receiving a command signal.

Abstract: An apparatus, method and system repair wellbore casing. In one embodiment, an expandable casing patch system for a wellbore includes a casing patch deployment apparatus. The casing patch deployment apparatus includes a shaft having a frontward end and a rearward end as well as a thruster and a main expansion swage disposed on the shaft. The casing patch deployment apparatus also includes an anchor disposed on the shaft. The anchor is disposed frontward of the main expansion swage. In addition, the casing patch deployment apparatus includes a front expansion swage disposed frontward of the anchor and attached to the shaft. The front expansion swage has a diameter less than a diameter of the main expansion swage. The expandable casing patch system also includes an expandable casing patch.

Abstract: Downhole tools that have a housing and an actuation mechanism. The actuation mechanism is adapted to index in response to one or more balls being deployed into said tool and thereafter to actuate in response to another said ball being deployed into said tool. The indexing balls and the actuation ball are substantially identical. The actuation mechanism may comprise a member adapted for indexing from an initial position sequentially through one or more intermediate positions to a terminal position where the indexed member is mounted in an annular space between an outer wall and an inner wall. The tool may comprise a central conduit which is substantially uniform internal diameter substantially free of profiles. Methods are provided that include deploying an ancillary tool through the tool which has not been actuated or drilled out.

Abstract: The method and device of exploitation of well by pumping unit with variable-frequency drive involes periodic repetition of the cycles including pumpdown, search for frequency when delivery stops and accumulation and at the same time to ensure such extraction of fluid from well which is equal to its inflow it is necessary to choose unit with higher capacity in comparison with inflow of fluid from formation into well and during the cycles the pumpdown-accumulation ratio is corrected depending on the results of the previous cycles until the pumpdown-accumulation time ratio stops to change and the torque at which the delivery stops is determined based on the equality of the current torque of the downhole motor shaft and check torque which is pre-determined based on stepwise drop of torque of the downhole motor shaft in the point when delivery stops when supply voltage is decreased.

Abstract: A tight-shale oil production tool includes a combustor operable to generate an aqueous-phase nitric acid, combustion products.

Abstract: Methods for treating subterranean wells in which the producing formation is a carbonate comprise preparing a treatment fluid comprising either: (a) an aqueous solution of a multivalent-cation reacting polymer; (b) a solution comprising a fatty acid and an ethanolamine; (c) an aqueous acidic solution of one or more compounds whose calcium salts are insoluble; or (d) an aqueous solution comprising urea or alkane derivatives thereof or both and polyvinylpyrrolidone (PVP). The treatment fluid is placed in the well such that the solution contacts the carbonate formation at a pressure higher than or equal to the fracturing pressure. The treatment fluid is allowed to react with the carbonate formation, thereby depositing a film onto the formation surface or parts of the formation surface. Then an acid solution is placed in the well such that the acid contacts the carbonate formation at a pressure higher than or equal to the fracturing pressure.

Abstract: Fluid end for high pressure reciprocating pump, in particular for hydraulic fracturing pumps, comprising: a body having a first bore (18) for receiving a reciprocating plunger (31), a second bore (19) for accommodating a suction valve (41), and a third bore (21) for accommodating a discharge valve (43), the second bore (19) and the third bore (21) being perpendicular to the first bore (18); at least a tubular sleeve (30) in said first bore (18); at least a tubular cartridge (30) in the second bore and/or third bore; and a fluid tight seal between contacting surfaces of said sleeve (30) and said cartridge (30).

Abstract: A system includes an integrated manifold system including multiple isobaric pressure exchangers (IPXs) that each includes a low-pressure first fluid inlet, a high-pressure second fluid inlet, a high-pressure first fluid outlet, and a low-pressure second fluid outlet. The integrated manifold system includes a low-pressure first fluid manifold coupled to each of the low-pressure first fluid inlets and configured to provide low-pressure first fluid to each of the low-pressure first fluid inlets, a high-pressure second fluid manifold coupled to each of the high-pressure second fluid inlets and configured to provide high-pressure second fluid to each of the high-pressure second fluid inlets, a high-pressure first fluid manifold coupled to each of the high-pressure first fluid outlets and configured to discharge high-pressure first fluid, and a low-pressure second fluid manifold coupled to each of the low-pressure second fluid outlets and configured to discharge low-pressure second fluid.

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: The present invention discloses a deepwater drilling condition based marine riser mechanical behavior test simulation system. An upper three-component dynamometer, an tipper connecting structure, a marine riser, a lower connecting structure and a lower three-component dynamometer are connected between an upper trailer connecting plate and a lower trailer connecting plate in sequence. The invention further discloses a test method. The present invention has the advantages that the mechanical behavior of the marine riser under deepwater drilling condition and marine environment coupling effect can be simulated comprehensively and accurately, and the apparatus can simulate ocean current environment, apply top tension to the marine riser, simulate circulation of internal drilling fluids at different current rates, simulate rotation of the drill stem at different rotational speeds and apply different drill pressures.

Abstract: A system and method for surface steerable drilling are provided. In one example, the system receives feedback information from a drilling rig and calculates an estimated position of a drill bit in a formation based on the feedback information. The system compares the estimated position to a desired position along a planned path of a borehole. The system calculates multiple solutions if the comparison indicates that the estimated position is outside a defined margin of error relative to the desired position. Each solution defines a path from the estimated position to the planned path. The system calculates a cost of each solution and selects one of the solutions based at least partly on the cost. The system produces control information representing the selected solution and outputs the control information for the drilling rig.

Abstract: A method of performing a cementing operation with an expandable cement deployable into a wellbore penetrating a subterranean formation is provided. The method involves determining design parameters of a wellsite, determining at least one estimated eigenstrain of the expandable cement based on the design parameters, selecting the expandable cement based on the estimated eigenstrain, and validating the selected expandable cement by comparing the estimated eigenstrain with the empirical eigenstrain. The design parameters includes a minimum pre-stress of the wellbore sufficient to prevent creation of a microannulus in the wellbore. The estimated eigenstrain is sufficient to generate the determined minimum pre-stress.

Abstract: An apparatus is adapted to be coupled to a component of a system associated with a wellhead. The apparatus includes a band adapted to be coupled to the component; a buckle coupled to the band and located proximate to a first end of the band; a holder coupled to the band, wherein the holder is positioned, or is adapted to be positioned, proximate to the first end; an electronic identifying device attached to the holder and adapted to identify the component; and an identifying component coupled to the band. The identifying component visually conveys information about at least one of: the electronic identifying device, and the component to which the band is adapted to be coupled. In one embodiment, the system associated with the wellhead is a system for pumping fluid to the wellhead. In one embodiment, the electronic identifying device is, or includes, an RFID chip.

Abstract: A downhole tool operable for conveyance within a wellbore extending into a subterranean formation, and for obtaining one or more measurements of the subterranean formation, wherein the downhole tool comprises a sensor, a pressure housing containing the sensor and mounted on an external surface of the downhole tool, and a sliding stabilizer covering the pressure housing.

Abstract: Systems and methods are provided for producing a continuous survey of a previously drilled portion of a wellbore. The method includes receiving a plurality of stationary survey measurements taken at a corresponding plurality of locations along the portion of the wellbore. The method further includes receiving at least one continuous survey including a plurality of continuous survey measurements taken between a pair of stationary survey measurements of the plurality of stationary survey measurements. The method further includes combining the plurality of stationary survey measurements and the plurality of continuous survey measurements to produce the continuous survey of the portion of the wellbore.

Abstract: A downhole tool is disclosed for measuring wellbore geometry. The downhole tool may include a body with a bore extending at least partially therethrough. The body may include a radial recess. An arm may be movably coupled to the body at a first end portion of the arm. The arm may be within the radial recess in a retracted position and be pivotable in a radially-outward direction relative to the body to an expanded position. A measurement device coupled to the body may measure the pivoting motion of the arm. A piston coupled to the body may be movably coupled to a second end portion of the arm, and the piston may respond to changes in hydraulic pressure to pivot the arm between the retracted position and the expanded position.

Abstract: An apparatus for measuring at least one of downhole position and velocity. The apparatus includes a body. A roller is connected with the body, and a plurality of sensors is connected with the body. The plurality of sensors can acquire roller data and wellbore data. The roller data and wellbore data can be used to determine at least one of the velocity and position of the apparatus. The apparatus can also have an electronic module that is in communication with the plurality of of sensors.

Abstract: A magnetic system for determining the location of a wellbore component in a first string relative to a wellbore component in a second string. The system includes a circumferentially distributed array of magnets positioned in the first string that is operable to produce a magnetic field in the wellbore proximate the location of the array of magnets. A magnetic field detector is operably associated with the second string and is operable to detect a magnetic signature of the magnetic field. One of the first and second strings is stationary within the wellbore. The other of the first and second strings is moveable in the wellbore such that the magnetic field detector is moveable relative to the magnetic field and such that when the magnetic field detector identifies the magnetic signature, the location of the array of magnets is correlated with the magnetic field detector.

Abstract: The present invention relates to a completion component having a circumference for insertion into a well tubular structure, comprising a tubular base part having an axial extension and a thickness and being adapted to be mounted as part of the well tubular structure, and a displaceable part having a thickness and being displaceable in relation to the tubular base part from a first position to a second position, wherein the tubular base part comprises a plurality of first markers and the displaceable part comprises a second marker for determining a position of the displaceable part in relation to the tubular base part, the first and second markers being arranged with a marker distance, wherein the first markers are different in geometrical size or material, or arranged with a varying mutual distance.

Abstract: Methods and related apparatus pertaining to downhole and surface telemetry, such as a method in which a telemetry system is provided with a communication path formed with an electrically conductive transport medium coupled across a plurality of downhole nodes. Such method includes operating on the communication path with a multi-drop system that provides telemetry to the downhole nodes in a wellbore, including employing modulation in a master-slave arrangement using binary differential phase shift keying or differential quadrature phase shift keying.

Abstract: A drillstring communications system includes one or more pipe segments, a communication sub coupled to the pipe segment that includes a communication sub antenna, and a leaky feeder antenna in communication with the communication sub antenna.

Abstract: A system including, a first component of a mineral extraction system, and a first radio frequency identification (RFID) module coupled to the first component, wherein the first RFID module comprises first component data relating to the first component, and first location data relating to a first location of the first component.

Abstract: A logging while drilling tool for measuring a geological formation surrounding a wellbore includes a tool body having one or more sensor pads. Each sensor pad is coupled to the tool body by an extendable coupling that is operable to adjust the radial position of the sensor pad by extending away from or retracting toward the tool body. One or more sensors are mounted to each sensor pads and the sensors are operable to obtain a measurement a property of the formation. The tool also includes a downhole control unit having a transmitter and receiver. The downhole control unit is operable to receive the measurement and transmit the measurement to a surface controller, wherein the transmitted measurement indicates a measurement resolution.

Abstract: Systems and methods for extracting and analyzing formation fluids from solids circulated out of a subterranean formation are provided. In one embodiment, the methods comprise: providing a sample of formation solids that have been separated from a fluid circulated in at least a portion of a well bore penetrating a portion of a subterranean formation at a well site; performing a solvent extraction on the sample of formation solids using one or more solvents at an elevated pressure at the well site, wherein at least a portion of one or more formation fluids residing in the formation solids is extracted into the one or more solvents to produce an extracted fluid; and analyzing the extracted fluid at the well site to determine the composition of the extracted fluid.

Abstract: Systems and methods for optical fluid identification approximation and calibration are described herein. One example method includes populating a database with a calculated pseudo optical sensor (CPOS) response of a first optical tool to a first sample fluid. The CPOS response of the first optical tool may be based on a transmittance spectrum of a sample fluid and may comprise a complex calculation using selected components of the first optical tool. A first model may be generated based, at least in part, on the database. The first model may receive as an input an optical sensor response and output a predicted fluid property. A second model may also be generated based, at least in part, on the database. The second model may receive as an input at least one known/measured fluid/environmental property value and may output a predicted pseudo optical sensor response of the first optical tool.

Abstract: A gas extraction system for gas analysis is provided. The gas extraction system includes the use of a peristaltic pump for moving condensates to a liquid trap assembly. An improved fluid flow is thus provided, which includes delivering condensate from a condensate separator to a peristaltic pump and delivering the condensate from the peristaltic pump to a liquid trap assembly.

Abstract: Obtaining in-situ, at a first time, first optical spectral data associated with a formation fluid flowing through a downhole formation fluid sampling apparatus, and then obtaining in-situ, at a second time after the first time, second optical spectral data associated with the formation fluid flowing through the downhole formation fluid sampling apparatus. A wavelength-independent scattering intensity within the formation fluid flowing through the downhole formation fluid sampling apparatus is then determined based on the first and second optical spectral data, and a wavelength-dependent scattering intensity within the formation fluid flowing through the downhole formation fluid sampling apparatus is determined based on the first and second optical spectral data.

Abstract: An improved cutting link and drive pin retention system for mining chains is disclosed. The cutting link is cast as a single piece instead of multiple parts welded together. The drive pin retention system further decreases the chance that the chain can break due to sheared dowel pins.

Abstract: A tool for mounting a chisel on a chisel holder, having an actuating member, which has a push-off section, wherein the actuating member can be displaced along a displacement direction. It is possible to simplify changing the chisel if the actuating member can be shifted by an actuating unit. The actuating unit has a draw-in section, which is spaced apart from the push-off section and is arranged transversely with respect to the displacement direction of the actuating member. The actuating member can be power-operated bidirectionally in the displacement direction by the actuating unit.

Abstract: Embodiments of the invention generally relate to tunnel boring machine cutter assemblies, such as ripping and scraping cutter or tool assemblies, (collectively “cutter assemblies”), and related methods of use and manufacturing. The various embodiments of the cutter assemblies described herein may be used in tunnel boring machines (“TBMs”), earth pressure balance machines (“EPBs”), raise drilling systems, large diameter blind drilling systems, and other types of mechanical drilling and excavation systems.

Abstract: Methods for balancing rotating machinery, such as gas turbine engines, to minimize vibrations. An optimal engine balance solution is obtained using a hybrid optimization technique based on vibration data from one or more vibration sensors and corresponding influence coefficients which quantify the change in vibration level at the vibration sensors due to a unit increase in unbalance level at unbalance source locations. More specifically, balance weight and angular position are determined based on multiple optimization methods which concurrently process the vibration data, the multiple optimization methods comprising local and global optimization algorithms.

Abstract: A gas turbine engine includes an axial high pressure compressor includes a rear hub disposed aft of an aft rotor segment. The rear hub includes an inner surface, an outer surface, and a sealing face, wherein the sealing face is sealingly engaged with the aft rotor segment, and in fluid communication with the cooling channel. The cooling channels are configured to delivery air to contact the inner surface of the rear hub.

Abstract: A rotor blade for a turbine engine includes an airfoil that is connected to a base. The base includes a platform, a neck and a fillet. The fillet extends along at least a portion of an intersection between the platform and the neck. The fillet has a radius that substantially continuously changes as the fillet extends from the platform to the neck.

Abstract: An airfoil of a turbine engine includes pressure and suction sides that extend in a radial direction from a 0% span position at an inner flow path location to a 100% span position at an airfoil tip. The airfoil has a relationship between a tangential stacking offset and a span position that is at least a third order polynomial curve that includes at least one positive and negative slope. The positive slope leans toward the suction side and the negative slope leans toward the pressure side. An initial slope starts at the 0% span position is either zero or positive. The first critical point is less than 15% span.

Abstract: A composite fan blade for a gas turbine engine is disclosed. The fan blade may include a core being made of a first material and a shell enclosing the core. The shell may be made of a second material and the second material may have less plasticity than the first material.

Abstract: An airfoil includes a cooling air passage for receiving a cooling air flow. A chevron including a first rib and a second rib extends from a common tip is disposed within the cooling passage for generating a turbulent flow to improve heat transfer. The chevron includes an angle between the first rib and the second rib that is greater than 90 degrees.

Abstract: A rotor for a gas turbine engine according to an exemplary aspect of the present disclosure includes, among other things, a rotor disk rotatable about an axis and a gas path wall coupled to and radially outward of the rotor disk. The gas path wall bounds a radially inward portion of a gas path. A plurality of rotor spokes are radially intermediate the rotor disk and the gas path wall. The plurality of rotor spokes is circumferentially spaced to define a plurality of cooling channels intermediate the rotor disk and the gas path wall. A thermal barrier coating is disposed on a surface of at least one of the plurality of cooling channels. A method of cooling a rotor assembly is also disclosed.

Abstract: An airfoil for a gas turbine engine includes a body having leading and trailing edges joined by spaced apart pressure and suction sides to provide an exterior airfoil surface defined by a perimeter wall. An interior wall is arranged interiorly and adjacent to the perimeter wall to provide a cooling passage there between. A cooling passage with first and second portions is tapered and respectively has first and second thicknesses. The first thickness is greater than the second thickness. The second thickness is less than 0.060 inch (1.52 mm).

Abstract: A turbine blade comprises an airfoil. An outer shroud at a tip of the airfoil, has a main surface facing the airfoil and forming a first plateau. A gusset or gussets have a periphery raising from the main surface, and a second plateau between the periphery and the airfoil. A gas turbine engine with such turbine blade is also provided.

Abstract: The fan comprises a fan disk able to be rotationally driven about a longitudinal axis and provided at the periphery with radial blades each comprising a root slideably engaged in a groove of the disk and, on the outside thereof, a vane, platforms surrounding the disk being interposed between the radial blades. Advantageously, the fan additionally comprises shock-absorbing wedges which are arranged tangentially at the exterior periphery of said disk underneath the platforms and between two roots of adjacent radial blades, each wedge being in tangential contact with the two adjacent blades.

Abstract: A composite ceramic turbine blade includes a ceramic airfoil portion and a ceramic outer tip shroud portion. The ceramic outer tip shroud portion is joined to the ceramic airfoil portion by a bonding means. In an embodiment, the bonding means comprises partial transient liquid phase bonding. In another embodiment, the airfoil portion is a fiber reinforced ceramic.

Abstract: A coating process and coated article are provided. The coating process includes providing a turbine component, applying a coating repellant to a predetermined region of the turbine component, and depositing a coating material on the turbine component. The coating repellant directs the coating material away from the predetermined region of the turbine component, to at least partially form a channel. A coating process for a hot gas path turbine component and coated article are also disclosed.

Abstract: A method of preventing transfer of metal of a gas turbine rotor blade having a metal tip to a blade outer air seal coating on a gas turbine case includes forming a coating on the metal tip. The coating comprises a bond coat layer on the metal tip and a ceramic filled metallic layer having a ceramic component in a matrix of a metal MCr, MCrAl, MCrAlY or a refractory modified CMCrAlY where M is nickel, cobalt, iron or mixtures thereof.

Abstract: A fan blade and method of manufacturing a fan blade includes a metallic fan blade body with a crystalline oxidation layer and immersing the crystalline oxidation layer in a solution of ceramic nanosheets in suspension. A fan blade for a gas turbine engine includes a metallic fan blade body having a tip with a crystalline oxidation layer, wherein the crystalline oxidation layer includes pores containing ceramic nanosheets.