Abstract: The debris catch provides a strainer located downstream of a rotating control device (RCD) within a flow line. The strainer is located between the RCD and at least one protected component. The strainer limits the debris and other junk that flows to protected components located downstream of the strainer. A first sensor and a second sensor detect the pressure differential between a location before the strainer and at the strainer. The two sensors detect a clog in the strainer. The strainer is removable through an access outlet for clearing the clog and reinstalling a strainer for continued drilling operation. A purge valve located in the system also allows clearing of the strainer by releasing the debris through a purge outlet located on a pathway separate from the pathway to the protected component.

Abstract: Techniques for separating cuttings from liquid include circulating a drilling fluid that comprises a liquid and formation cuttings to a scree of a screen assembly that includes screen sections; vibrating the screen assembly during circulation of the drilling fluid; while vibrating the screen assembly, separating the liquid from the plurality of formation cuttings; while vibrating the screen assembly, separating a first portion of the formation cuttings of a first size from the drilling fluid with a first screen section; rotating the screen assembly; subsequent to rotating the screen assembly and while vibrating the screen assembly, separating a second portion of the formation cuttings of a second size different than the first size from the drilling fluid with a second screen section; directing the separated liquid through the screen assembly to a liquid outlet; and directing at least one of the first or second portions of the formation cuttings to a cuttings outlet formed in the screen.

Abstract: Control of a drilling system drilling a wellbore is improved using a hydraulic model corrected for pressure losses. A surface backpressure of the outlet and a standpipe pressure of the inlet are measured with sensors in the system. An estimate of the standpipe pressure is calculated based integrating from the measured surface backpressure back to the inlet in the hydraulics model. The pressure loss increment in the hydraulics model is calculated based on a difference between the measured and estimated standpipe pressures. Meanwhile, a parameter in the drilling system is monitored during drilling so the parameter can be adjusted at least partially based on the hydraulics model corrected for the pressure loss.

Abstract: A method of separating a downhole tubular includes running a tool into a wellbore to a predetermined location on a work string and actuating flow actuated slips. The method also includes maintaining slips in a set position by providing a first upward force on the work string. The method further includes rotating the work string to separate an upper portion of the tubular from a lower portion using a cutter assembly disposed on the work string below the slips and pulling the upper portion of the tubing and the tool from the wellbore.

Abstract: An anchor for securing a well tool can include a longitudinally extending central axis, an outwardly extendable grip member, and a mechanical linkage including multiple pivotably connected links. The links pivot relative to each other in a plane laterally offset from the central axis. A method of anchoring a well tool can include flowing a fluid through an anchor connected to the well tool, thereby outwardly extending a grip member into contact with a well surface, and applying a tensile force to the anchor, thereby increasingly biasing the grip member against the well surface and securing the well tool relative to the well surface. A method of anchoring a tubing cutter in a tubular string can include applying a tensile force from an anchor to the tubular string, and cutting the tubular string while the tensile force is applied from the anchor to the tubular string.

Abstract: Examples of the present disclosure relate to systems and methods for mapping a wellbore for refracturing. More specifically, embodiments are directed towards utilizing downhole pressure data to identify previously untreated clusters, clusters with cross contamination, and clusters with proper zonal isolation with full pressure integrity.

Abstract: A sealed pressured horizontal directional drilling continuous coring device for engineering geological investigation includes an outer tube assembly and an inner tube assembly matching the outer tube assembly. The outer tube assembly includes a single-wall drill pipe and a dual-wall drill pipe assembly. The inner wall of the dual-wall drill pipe assembly is sequentially provided with a bullet stop head, a bullet room, a suspended seat ring, a positioning inner lock, a positioning outer lock, a first centralizing ring, a lock ring seat and a drill from top to bottom. The inner tube assembly includes a spear head, a first sealing component, a bullet positioning mechanism, a recovery pipe, a second sealing component, an in-place reporting mechanism, a core blockage alarm mechanism, a single-action mechanism, a guiding mechanism, a buffer mechanism, an adjustment mechanism, a core tube and a core clamping mechanism.

Abstract: A wellbore assembly includes a cable configured to be disposed within a wellbore. The wellbore assembly also includes a housing attached to a downhole end of the cable. The housing defines a fluid outlet at a downhole end of the housing. The housing includes an anchor and a collapsible gate. The anchor engages a wall of the wellbore under increased tension in the cable, thereby anchoring the housing to the wellbore. The collapsible gate is disposed inside the housing between an uphole end of the housing and the fluid outlet. The housing temporarily stores a treatment fluid configured to treat an obstruction in the wellbore. The collapsible gate is configured to break, with the anchor engaged, under further tension applied by the cable, inside the housing to allow the treatment fluid to flow out of the housing through the fluid outlet toward the obstruction.

Abstract: The present invention relates to a downhole line separation tool for submerging into a casing in a wellbore, the downhole line separation tool having a first tool end, a second tool end and a tool axis, comprising a tool housing having a first housing part and a second housing part, an electrical motor arranged within the first housing part and powered through a wireline connected to the first tool end, an annular separation element having an element end facing away from the first tool end and being rotatably connected within the second housing part, and a rotatable shaft arranged within the second housing part and rotated by the electrical motor for rotating the annular separation element, wherein the second housing part comprises a sleeve part having a sleeve end, at least part of the annular separation element projecting from the sleeve end further away from the first tool end than the sleeve, the second housing part comprising at least one projecting part extending further away from the first tool end tha

Abstract: Systems and methods measure one or more rheological properties and/or parameters of a fluid and establish at least one correlation between the measured one or more rheological properties and/or parameters. The systems and methods may correlate the measured one or more rheological properties and/or parameters to static aging results to establish the at least one correlation between the one or more rheological properties and/or parameters of the fluid. The systems and methods may predict at least one sagging tendency of the fluid based on the established at least one correlation and may measure and/or monitor static sagging of the fluid based on the predicted at least one sagging tendency of the fluid. The systems and methods may guide fluid treatment of the fluid or produce a mud system based on the predicted at least one sagging tendency of the fluid.

Abstract: A downhole device that drills a wellbore includes a stabilizer which has a body and blades. The blades are disposed on a surface of the body and each blade has a hollow space. The blades each include a dissolvable window that is disposed on a surface of each of the blades and a light source that emits light to the wellbore. The dissolvable window blocks light emitted from the light source thereby reducing or eliminating light from being transmitted to the wellbore. The dissolvable window dissolves upon exposure to a fluid containing a dissolving medium, thereby allowing the light source to transmit light to the wellbore. Methods of using the downhole device to activate downhole chemicals are also provided.

Abstract: A modular pressure cylinder for a downhole tool has an active mandrel tube that supports a modular pressure cylinder. Pistons of the modular pressure cylinder are respectively interconnected and cylinder walls of modular pressure cylinder are respectively interconnected. When fluid is pumped through a tubing string into the downhole tool, the pistons are urged in one direction while the cylinder walls are urged in an opposite direction along an axis of the active mandrel tube.

Abstract: An uphole end for a compression-set straddle packer has a multicomponent mandrel and a multicomponent sliding sleeve that reciprocates within a limited range on the multicomponent mandrel. A bias element constantly resists relative movement between the multicomponent mandrel and the multicomponent sliding sleeve.

Abstract: A wellbore is plugged using a bismuth alloy. The wellbore is arranged so that a liquid bismuth alloy sets with an excess pressure of the plug relative to the borehole fluid pressure along a desired seal height distance.

Abstract: This disclosure presents an apparatus to improve the indication of an amount that a fluid valve is opened. The fluid control assembly includes an improved position sensor assembly (PSA), where the PSA uses rollers rather than sliding within the PSA housing. The rollers, which can be wheels, ball bearings, and other types of rolling devices, can reduce the friction experienced by the moving component within the PSA. Since the PSA mechanism can move with less friction, the coupled valve magnetic assembly (VMA) can also be enhanced. The VMA can utilize magnets in orientations that enhance the magnetic tensile and compressive forces. For example, some magnets in the VMA can be in a perpendicular orientation to improve directional control and some magnets can be in an angled orientation to reduce the spread of the magnetic field flux lines between the magnets of the VMA and the magnets of the PSA.

Abstract: Degradable downhole tools, tool components, and balls are formed from a processed polyvinyl alcohol (PVA) compound that is degradable in a high-salinity environment. The PVA compound exhibits strength and elasticity properties that are comparable to existing degradable downhole polymers and further exhibits degradability properties that are superior to existing degradable downhole polymers, particularly in high-salinity fluids. For different components, the PVA compound may include a reinforcing material such as fiberglass. The PVA compound also includes a loading of degradable metal, such as a degradable magnesium alloy, rendering the material degradable at high salinity. Usage of tools, tool components, and balls formed from the disclosed materials eliminates the requirement that such equipment be drilled out after use as the PVA compound quickly degrades in high-salinity downhole fluids.

Abstract: Provided is an electrically surface-controlled subsurface safety valve (ESCSSV). The ESCSSV, in one example, includes an outer housing comprising a central bore extending axially through the housing that is configured to convey production fluids there through. The ESCSSV, in this embodiment, further includes a valve closure mechanism disposed proximate a downhole end of the central bore, and a bore flow management actuator disposed in the central bore and configured to move between a closed state and a flow state to engage or disengage the valve closure mechanism to determine a flow condition of the production fluids through the central bore. The ESCSSV, in this embodiment, additionally includes an electric valve assembly fluidically coupled to the bore flow management actuator and configured to select between a section pressure or the annulus pressure to control the bore flow management actuator and determine the flow condition of production fluids through the central bore.

Abstract: A system includes a sliding sleeve valve including a valve body and an inner sleeve selectively shiftable within the valve body, at least one flow port contained in the valve body, at least one metal to metal seal provided between an inside wall of the valve body and the inner sleeve, and a shifting tool. The inner sleeve of the sliding sleeve valve includes a plurality of selective profiles, and the shifting tool is engageable with the plurality of selective profiles of the inner sleeve. The shifting tool includes two halves that each include a recess for accommodating a plurality of control lines.

Abstract: A downhole valve includes a housing, and a sleeve positioned within the housing. The sleeve has a first axial end, a second axial end, and a seat positioned between the first and second ends. The sleeve defines an opening facing in a radial direction. The sleeve prevents fluid flow in an opposite radial direction, away from the opening. The valve also includes a retaining element coupled to or integral with the sleeve, and a first obstructing member positioned in the sleeve and movable between the seat and the retaining element. In a first position, the first obstructing member engages the seat and prevents fluid flow through the housing. In a second position, the first obstructing member is separated apart from the seat such that at least a portion of the opening is axially between the first obstructing member and the first obstructing member.

Abstract: A method of configuring a flow control valve of a mixing system may comprise establishing a flow loop via a pump, a flow control valve, and a flow rate sensor. The method may also include performing a valve configuration process that includes positioning the flow control valve in a first position, operating the pump to communicate a fluid via the flow loop at a first speed, measuring a first periodic dataset while the fluid is communicated via the flow loop, and recording the first periodic dataset. The method may also include comparing a result of the valve configuration process to a valve position dataset and an operational indicator set and determining an pass/fail status based upon the comparison, and outputting, by the unit controller, indicia of the pass/fail status of the mixing system via the input output device.

Abstract: A downhole system includes a drill string having a drilling fluid flow channel and at least one turbine alternator deployed in the flow channel. The turbine alternator is configured to convert flowing drilling fluid to electrical power. A voltage bus is configured to receive electrical power from the turbine alternator and at least one electrical motor is configured to receive electrical power from the voltage bus. An electronic controller is configured to provide active control of the turbine alternator via processing a desired speed of the electrical motor to generate a desired torque current and feeding the desired torque current forward to the turbine alternator. The turbine alternator is responsive to the desired torque current such that it modifies the electrical power provided to the voltage bus in response to the desired torque.

Abstract: A GLV-gas lift valve that employs TSMS-two simultaneous mechanical stops, first one when SEWB-single edge welded bellow 8 is fully compressed to solid by valve dome pressure 5 and second mechanical stop where adjustable sealing arrangement with compressible seal 25, threaded regulating nut 17 and threaded jam nut 18 are compressed against orifice 15, compressible seal 25 is fully compressed into groove 30, gap 26 is fully exhausted, dimension L reaches zero, and gap 31 is completely exhausted, providing second mechanical stop between TC ball 14 and orifice 15. Sealing arrangement can be TC-Tungsten carbide ball 14 butted against orifice 15, flat, conical or curved sealing surface containing said compressible seal, that is solidly compressed against SEWB or DEWB, thus providing second mechanical stop and sealing fluid flow through GLV. Compressing SEWB/DEWB to full solid protects bellow from high dome pressure 5 while “Fortress Seal™” per U.S. Pat. No.

Abstract: An electric submersible pumping system is constructed with an outer housing which contains an integrated pump and motor. The pump may comprise an impeller disposed within a stator of the motor to form an integrated pump and the motor. An electric submersible pumping system includes a stator having a passage extending longitudinally through the stator. A plurality of stages, including impellers and diffusers, are disposed within the passage.

Abstract: A method for recovering subsurface fluid from rock formations by adding an enzyme-based green solvent to a carrier fluid and injecting the enzyme-based green solvent and the carrier fluid into a production well. The enzyme-based green solvent and the carrier fluid are directed down a flow path of the production well. The solvent soaks in the production well before reversing the flow path of the production well. The enzyme-based green solvent and the carrier fluid travel up the flow path with a plurality of recovered deposits from the production well in the enzyme-based green solvent.

Abstract: System and methods for simulating fluid flow during downhole operations are provided. Measurements of an operating variable at one or more locations within a formation are obtained from a downhole tool disposed in a wellbore within the formation during a current stage of a downhole operation being performed along the wellbore. The obtained measurements are applied as inputs to a hybrid model of the formation. The hybrid model includes physics-based and machine learning models that are coupled together within a simulation grid. Fluid flow within the formation is simulated, based on the inputs applied to the hybrid model. A response of the operating variable is estimated for a subsequent stage of the downhole operation along the wellbore, based on the simulation. Flow control parameters for the subsequent stage are determined based on the estimated response. The subsequent stage of the operation is performed according to the determined flow control parameters.

Abstract: A method of increasing hydrocarbon recovery from a wellbore in a tight formation with greater breakdown pressures, the method including using hydro-jetting to effect a plurality of oriented cavities or discoidal grooves in the horizontal portion of the wellbore to overcome near-wellbore stresses, injecting a thermally controlled fluid into the wellbore to alter the temperature of the formation and lower stresses, and then fracturing the formation to generate a series of fractures that can be formed in a planar formation.

Abstract: Embodiments of drive equipment for mobile hydraulic fracturing power units and methods for changing and controlling the drive equipment are disclosed. The mobile power units include a gas turbine engine that provides mechanical power to drive shaft which is connected to the drive equipment such that the drive equipment is driven by the engine. The drive equipment may be a hydraulic fracturing pump or an electrical generator. The drive shaft is rotated at a speed suitable for the hydraulic fracturing pump and the electrical generator includes a step up gearbox to increase a rotational speed of the drive shaft for use by the electrical generator. The drive equipment may be secured to a skid that is field changeable with a crane or a fork lift to change the drive equipment at a well pad based on the demands of the well pad.

Abstract: A pumping system is configured to be deployed in a well that has a vertical portion and a lateral portion. The pumping system includes a pump positioned in the vertical portion, a velocity tube assembly that extends from the vertical portion into the lateral portion and a cyclonic solids separator connected between the pump and the velocity tube assembly. The cyclonic solids separator includes a housing, a discharge manifold extending through the housing, and a plurality of ejection ports that extend through the discharge manifold along arcuate, tangential paths.

Abstract: A downhole tool for preventing pump blockage includes an outer conduit defining an outer flow path, an inner conduit located within the outer conduit defining an inner flow path and a space between the inner conduit and the outer conduit. The inner conduit includes one or more angled passageways to allow one-way debris flow. A pressure regulated valve is coupled to the upper end of the outer conduit and configured to open to expand an adjustable width angled passageway defined by the pressure regulated valve. An upper end of the inner conduit is configured to allow fluid bypass of the angled passageways of the inner conduit when the angled passageways are blocked with debris.

Abstract: Aspects and features of a system for real-time drilling using automated data quality control can include a computing device, a drilling tool, sensors, and a message bus. The message bus can receive current data from a wellbore. The computing device can generate and use a feature-extraction model to provide revised data values that include those for missing data, statistical outliers, or both. The model can be used to produce controllable drilling parameters using highly accurate data to provide optimal control of the drilling tool. The real-time message bus can be used to apply the controllable drilling parameters to the drilling tool.

Abstract: An apparatus, system and/or method for making observations down a wellbore are provided. The wellbore observation system may comprise a mandrel that can be run downhole, and telescoping tracks can be utilized to move a camera and semi-conforming inflatable bladder out of the mandrel and into the wellbore. Once the bladder is inflated, it displaces high turbidity fluid in the wellbore to allow the camera to move about a track and observe the wellbore unobstructed. An alternative embodiment allows the mandrel and telescoping tracks to be utilized with other tools to perform cleaning, fishing, diagnostic, and analytic operations.

Abstract: A method includes deploying a logging tool in a borehole formed in a subsurface formation, the logging tool having a transmitter and a receiver, wherein a condition that is present during logging comprises at least one of a shape of the borehole is non-circular and the logging tool is off-center within the borehole. The method includes emitting, by the transmitter, a signal into subsurface formation and detecting, by the receiver, a response to the signal being propagated through the subsurface formation. The method includes creating, from the response, a borehole image that includes features in the subsurface formation and correcting the features, wherein correcting the features comprises mapping points of a non-circular shape in the borehole image into a plane substantially perpendicular to an axis of the borehole.

Abstract: Providing diagnostics or monitoring operation of a rod pressure includes using waves in production fluid produced by the rod pump may be used to determine one or more operating states of the rod pump. The one or more operating states of the rod pump may be used by a user to diagnose or monitor the operation of the rod pump.

Abstract: Method and system for developing reservoirs, such as hydrocarbon reservoirs or aquifers, including correcting pressure transient test data to account for variations of fluid density between a gauge depth and a mid-reservoir depth in a wellbore. Gauge depth pressure and temperature measurements, and density correlations are used to estimate mid-reservoir depth pressures, which can be used in a pressure transient analysis.

Abstract: A method of detecting an event by: obtaining a first sample data set; determining a frequency domain feature(s) of the first sample data set over a first time period; determining a first threshold for the a frequency domain feature(s) using the first sample data set; determining that the frequency domain feature(s) matches the first threshold; determining the presence of an event during the first time period based on determining that the frequency domain feature(s) matches the first threshold; obtaining a second sample data set; determining a frequency domain feature(s) of the second sample data set over a second time period; determining a second threshold for the frequency domain feature(s) using the second sample data set; determining that the frequency domain feature(s) matches the second threshold; and determining the presence of the event during the second time period based on determining that the frequency domain feature(s) matches the second threshold.

Abstract: Systems, methods, and apparatus for determining permeability of subsurface formations are provided. In one aspect, a method includes: positioning a sample of the subsurface formation in a measurement cell, fluidly connecting an inlet and an outlet of the sample to an upstream reservoir and a downstream reservoir, respectively, flowing a fluid through the sample from the upstream reservoir to the downstream reservoir, measuring changes of an upstream pressure associated with the upstream reservoir and a downstream pressure associated with the downstream reservoir in a measurement time period, and determining a matrix permeability of the subsurface formation based on measurement data before the upstream pressure and the downstream pressure merge at a merging time point.

Abstract: A method of monitoring a reservoir comprising setting at least one barrier in a well separating it into upper and lower isolated sections. A perforating gun or other perforating device is provided in the lower isolated section, along with a control mechanism, wireless communication device and a pressure sensor. After the barrier is set, the perforating gun is activated in order to create at least one perforation between the well and a surrounding reservoir. The well, or part of it, is suspended or abandoned but the pressure is still monitored and a wireless, preferably acoustic or electromagnetic, data signal is transmitted from the lower isolated section to above the barrier. Data from the suspended/abandoned part of the well may be used to infer characteristics of the reservoir so that it may be exploited more appropriately especially through another well.

Abstract: A well tool assembly can include a well barrier and a detachable sub connected to the well barrier. The detachable sub can include a sensor data receiver. A method of retrieving sensor data can include positioning a sensor on one side of a well barrier, connecting a detachable sub on an opposite side of the well barrier, the detachable sub including a sensor data receiver configured to receive sensor data from the sensor, and conveying the well barrier, the sensor and the detachable sub together into a well. A system can include a sensor, a detachable sub, and a well barrier positioned between the sensor and the detachable sub, the detachable sub including a sensor data receiver, a passage extending longitudinally through the detachable sub, and a closure that selectively opens and blocks the passage.

Abstract: Distributed acoustic sensing (DAS) measurements may be acquired at an observation wellbore during a current stage of a stimulation treatment along a treatment wellbore within a reservoir formation. A cumulative strain trace for the current stage of the stimulation treatment may be determined based on the DAS measurements. Based on the cumulative strain trace, whether or not to adjust a spacing of perforation clusters and/or a stage length used at the treatment wellbore for a subsequent stage of the stimulation treatment may be determined. Responsive to determining to adjust the spacing of the perforation dusters or to adjust the stage length, at least one treatment parameter for the subsequent stage may be adjusted. The subsequent stage may be performed based on the adjusted at least one treatment parameter.

Abstract: A siphon pump chimney can be used in a mini-drillstem test to increase formation fluid flow rates. A formation tester can be coupled to a siphon pump chimney via a wet connect assembly to transfer formation fluid from a fluid-bearing formation. The siphon pump chimney can receive the formation fluid through the wet connect and disperse the formation fluid into a drill pipe that is flowing drilling fluid. The siphon pump chimney can include check valves to prevent the drilling fluid from entering the siphon pump chimney. The siphon pump chimney can be configured to have a variable height that can reduce pressure within the siphon pump chimney to a pressure value that can be close to or less than the formation pressure, which can allow a pump to operate at high flow rates or be bypassed in a free flow configuration.

Abstract: Provided, in one aspect, is a downhole tool. The downhole tool, according to this aspect, may include a helically wound structure having first and second ends, as well as a first member coupled to the first end and a second member coupled to the second end. In accordance with this aspect, the first and second members are rotatable or linearly translatable with respect to each other to move the helically wound structure between a radially retracted state having at least one coils and a radially deployed state.

Abstract: A transportation network for providing propellant in space can include optical mining vehicles that concentrate solar energy to spall captured asteroids, capture released volatiles, and store them in reservoirs as propellants. The network can also have orbital transfer vehicles that use solar thermal rocket modules that focus solar energy on heat exchangers to force propellant through nozzles, as well as separable aeromaneuvering tanker modules with reusable heatshields and storage tanks. The network can have propellant depots positioned between Earth and a transport destination. The depots can mechanically couple to accept propellant delivery and to supply it to visiting space vehicles.

Abstract: A rotating assembly for a gas turbine engine has a balancing ring mounted to a first rotating component having a rotating unbalance about an axis of rotation. The ring is clocked at a circumferential position about the axis to counteract the rotating unbalance. A spacer is axially abutted against the first rotating component to set an axial position of the first rotating component relative to a second rotating component. The balancing ring is locked against rotation relative to the first rotating component in its circumferential position by the dual use spacer.

Abstract: A rotor blade includes an airfoil having an airfoil shape. The airfoil shape has a nominal profile substantially in accordance with Cartesian coordinate values of X, Y and Z set forth in one of Table I, Table II, Table III, Table IV, Table V, Table VI, Table VII, Table VIII, or Table IX. The Cartesian coordinate values of X, Y and Z are non-dimensional values from 0% to 100% convertible to dimensional distances expressed in a unit of distance by multiplying the Cartesian coordinate values of X, Y and Z by a scaling factor of the airfoil in the unit of distance. The X and Y values, when connected by smooth continuing arcs, define airfoil profile sections at each Z value. The airfoil profile sections at Z values are joined smoothly with one another to form a complete airfoil shape.

Abstract: A stator vane includes an airfoil having an airfoil shape. The airfoil shape has a nominal profile substantially in accordance with Cartesian coordinate values of X, Y, and Z set forth in one of TABLE I or TABLE II. The Cartesian coordinate values of X, Y, and Z are defined relative to a point data origin at a base of the airfoil. The Cartesian coordinate values of X, Y, and Z are non-dimensional values that are convertible to dimensional distances expressed in a unit of distance by multiplying the Cartesian coordinate values of X, Y, and Z by a scaling factor of the airfoil in the unit of distance. The X and Y values are connected by smooth continuing arcs to define airfoil profile sections at each Z value. The airfoil profile sections at Z values are joined smoothly with one another to form a complete airfoil shape.

Abstract: A turbine blade is provided. The turbine blade may include an airfoil having an airfoil tip, a leading edge, a trailing edge, and a pressure side and a suction side extending from the leading edge to the trailing edge and defining an airfoil cavity, a squealer tip arranged at the airfoil tip part and comprising a trailing edge tip portion disposed at the trailing edge of the airfoil and a pressure side rail and a suction side rail meeting at the trailing edge tip portion and defining a squealer tip pocket at the airfoil tip, and at least one tip cooling hole disposed at the squealer tip pocket to provide cooling air from the airfoil cavity to the squealer tip pocket, wherein the trailing edge tip portion of the squealer tip includes a chamfer disposed towards the pressure side of the airfoil and a groove extending from the squealer tip pocket to the chamfer to provide cooling air from the squealer tip pocket to the chamfer.

Abstract: A turbine blade includes an airfoil body, and a plurality of cooling passages extending along a blade height direction inside the airfoil body and being in communication with each other to define a serpentine flow passage. The plurality of cooling passages include first turbulators on an inner wall surface of an upstream cooling passage of the plurality of cooling passages, and second turbulators on an inner wall surface of a downstream cooling passage of the plurality of cooling passages. A second angle formed by the second turbulators with respect to a flow direction of a cooling fluid in the downstream cooling passage is smaller than a first angle formed by the first turbulators with respect to the flow direction of the cooling fluid in the upstream cooling passage.

Abstract: A turbine stator blade made of ceramic matrix composite material includes a hollow blade profile and has a trailing edge and a leading edge, the blade including a first portion including an extrados face and a second portion distinct from the first portion including an intrados face, the first and second portions being connected to one another by a connection interface present at least on the trailing edge or leading edge, the connecting interface including a region of overlap between the first and second portions present on at least one longitudinal end of the blade profile and intended to be present outside a flow path of a gas stream of the turbine, the blade also including a platform present at a longitudinal end of the blade profile and that includes a first portion integral with the extrados face and a second part integral with the intrados face.

Abstract: An improved stator assembly for use in a gas-turbine engine is disclosed. The stator assembly may comprise a vane, an inner diameter (ID) ring, an outer diameter (OD) ring, a vane disposed between the ID ring and the OD ring, a potting component coupling the vane to at least one of the OD ring or the ID ring, and a potting embedded component disposed within the potting component. The potting embedded component may prevent disbond of the potting component during operation of the gas-turbine engine.

Abstract: The invention relates to a bleed air extraction device for a turbomachine, which has: an axial compressor, formed in a flow path and having at least one compressor stage, which comprises a rotor and a stator, and a bleed air duct, which is provided and designed to guide a bleed air flow branched off from the flow path of the axial compressor. In this case, the bleed air duct comprises an inlet opening, which is formed downstream of a stator of the axial compressor in the radially outer flow path boundary, an axially forward wall adjoining the inlet opening, and an axially rearward wall adjoining the inlet opening. Guide means are provided, which are provided and designed for the purpose of guiding at least a portion of the bleed air flow branched off from the flow path in the direction of the axially forward wall of the bleed air duct.