Abstract: A device which moves a die between a retracted position, thereby releasing the die from the device, and an advanced position, thereby fixing the die to the device. The device includes an inner body comprising an inner body wall, and an inner body set of inclined faces. A body comprises a longitudinal groove. The longitudinal groove comprises an inner wall which contacts the inner body wall. An intermediate body comprises a first longitudinal side comprising a longitudinal side set of inclined faces, and a second longitudinal side arranged opposite thereto. The first longitudinal side cooperates with the inner wall. The second longitudinal side cooperates with a first side of the die. The longitudinal side set of inclined faces cooperates with the inner body set of inclined faces. A relative movement between the intermediate body and the inner body moves the die between the retracted position and the advanced position.

Abstract: A mechanism for twisting off a drill rod includes a front clamping body (J0) and a rear clamping body (J1) both of which are installed at a fixed bracket. Each of the front clamping body (J0) and the rear clamping body (J1) includes a positioning clamping device and a clamping execution device which are respectively installed at two sides of a clamping centerline (JC) and opposite to each other. The front clamping body (J0) is installed within the first fixed bracket element (80) through a rear fixed shaft. The rear clamping body (J1) is installed within an overturn bracket (6) of the second fixed bracket element (81) through a rear fixed shaft. The positioning clamping device and the clamping execution device of both the front clamping body (J0) and the rear clamping body (J1) are asymmetric to each other.

Abstract: A wellbore treatment fluid comprising: a base fluid; and a fluid loss additive package, the fluid loss additive package comprising: a water-swellable, superabsorbent polymer; a derivatized cellulose; and non-swellable particles that are insoluble in the base fluid. A method of drilling a wellbore into a subterranean formation comprising: providing the drilling fluid; and forming the wellbore using a drill bit and the drilling fluid.

Abstract: A pre-mounted exchange insert of a drill wash device is disclosed for connecting a stationary washpipe to a rotating washpipe, which includes a mechanical seal assembly with a stationary seal ring and a rotating seal ring, a first seal ring carrier on which the stationary seal ring is arranged, a second seal ring carrier on which the rotating seal ring is arranged, a connection component which is configured to connect the exchange insert to the stationary washpipe, and an adjusting mechanism operative in an axial direction with a screw connection for changing an axial length of the exchange insert, wherein the screw connection is connected to the second seal ring carrier to permit, in an axial direction, an adjustment of the second seal ring carrier, the mechanical seal assembly, and the first seal ring carrier relative to the connection component.

Abstract: A system for separating components from a slurry of drilling fluid and drill cuttings on a shaker screen having an upper side and a lower side within a shaker. The system also has a pressure differential generator to pull an effective volume of air through a section of the shaker screen to enhance the flow of drilling fluid through the section of the shaker screen and the separation of drilling fluid from drill cuttings and further maintain an effective flow of drill cuttings off the shaker. A method of separating components of a slurry of drilling fluids and solids has the steps of delivering the slurry to a shaker, flowing the slurry over a first screen and applying an effective amount of vacuum to a first portion of the first screen to remove the drilling fluids from the slurry without stalling the solids on the first screen.

Abstract: A craneless elevatable MGS vessel and U-tube assembly can be delivered on a winch truck to a drilling site and assembled in a far shorter time and without the need of having a crane and crane operator attend to the movement and placement of the MGS vessel and attached U-tube mud lines to a mud handling system in a drilling rig. The MGS vessel of the present application can be a standard type of MGS vessel well known in the industry. By fabricating this MGS vessel with attached and moveable U-tube connectors for the mud line, the system can be moved and assembled at the drill site without crane intervention. Moreover, the ability to raise the MGS vessel, after placement in its vertical position, permits ready attachment to multiple diverse drilling rig configurations.

Abstract: A Coriolis flow meter for a drilling system measures flow from a wellbore and/or from at least one pump into the wellbore. The meter can be disposed upstream of at least one choke used for controlling backpressure, and/or the meter can be disposed between at least one pump and the wellbore. The meter has at least one flow tube adapted to vibrate and conducts the flow at a first pressure level from an inlet side to an outlet side. A vessel encloses the at least one flow tube at least between the inlet and outlet sides and holds a second pressure level therein about the at least one flow tube. The second pressure level can be equal to or nearly equal to the first pressure level to reduce or nearly eliminate a pressure differential across the at least one flow tube. For example, the second pressure level can be elevated above environmental relative to the first pressure level to reduce a pressure differential across the at least one flow tube.

Abstract: A drilling system for drilling a wellbore has one or more valves or chokes to control the upstream pressure of drilling fluid flow in a controlled pressure drilling operation. A measurement is obtained of the drilling fluid flow from the wellbore. Based on the obtained measurement, the drilling fluid flow is selectively distributed with a distributor through one or more of a plurality of flowmeters, such as Coriolis meters. A reading of the drilling fluid flow is obtained from the selected flowmeter(s). Upstream pressure in the drilling fluid flow is controlled with the one or more valve based at least in part on the reading from the one or more selected flowmeters. The reading can be a flow rate, a pressure, or the like compared to capacities of the flowmeters. Additional valves downstream of the flowmeters can be controlled based on cavitation that the valves are estimated to produce.

Abstract: A collector circuit and associated circulation process, for intercepting and selectively diverting, at least partially, a fluid flow continuously flowing in a fluid circulation system, for drilling rigs. The collector includes a first sub-circuit with a first duct, with a first valve, and a second duct with a second valve; and; a second sub-circuit; The first sub-circuit, depending on the operating configurations of the first valve and the second valve, is adapted to allow the transit of the fluid flow in the first duct, and selectively divert fluid flow towards the second duct. The second sub-circuit is fluid-dynamically connected to the second duct of the first sub-circuit for receiving fluid flow, diverted by the first sub-circuit, and directing it towards a first outlet of the second sub-circuit. The second sub-circuit and the first sub-circuit are independent, and the second sub-circuit is removable from the collector circuit.

Abstract: A casing hanger and running tool system and method for rotating a casing string in a borehole include a selectively engageable connection between the casing hanger and the running tool whereby upon rotation of the casing hanger and running tool in a first direction, a length of casing may be rotated without any substantial tightening of a threaded connection between the running tool and the casing hanger, and upon rotation of the running tool in a second direction, the threaded connection between the running tool and the casing hanger may be disengaged.

Abstract: A downhole tool anchor is disclosed. In one implementation, a downhole anchor tool may include a housing, an axial drive in the housing, a rack connected to the axial drive, a pinion in the housing, the pinion having teeth that engage teeth on the rack, a gear tube within the pinion, the gear tube having internal threads, a slip rod having external threads that engage the internal threads within the gear tube, and a radial bearing coupled to the gear tube, the radial bearing having a slip rod alignment member that prevents the slip rod from free spinning in the gear tube.

Abstract: It is sometimes necessary to sever a downhole tubular structure in the course of conducting subterranean operations. Detonation of an explosive material may be used to sever a tubular structure in some instances. Downhole severing tools may comprise: a housing; a two-stage energizing material within the housing, the two-stage energizing material comprising a high explosive and a reactive energizing material; at least one initiator coupled to the two-stage energizing material at least at a first location; and a detonator coupled to the at least one initiator; wherein upon detonation of the two-stage energizing material, the high explosive undergoes a primary reaction that propagates a secondary reaction of the reactive energizing material.

Abstract: An impact apparatus conveyable in a tool string within a wellbore comprises a mandrel, a first impact feature, and a latch pin retainer encircling an end of the mandrel. A release sleeve encircles a portion of the latch pin retainer and includes a radial recess. Latch pins retained by the latch pin retainer are slidable into and out of the radial recess, and prevent disengagement of the mandrel end from the latch pin retainer when not extending into the radial recess. A release member electromagnetically causes relative translation of the latch pin retainer and the release sleeve, including aligning the latch pins with the radial recess and thereby permitting the disengagement. A second impact feature is positioned to impact the first impact feature in response to the disengagement when the impact apparatus is under tension.

Abstract: A wellhead assembly includes a wellhead housing having a bore with a wellhead housing sidewall and a longitudinal axis. A hanger lands in the bore, the hanger having a hanger sidewall. Parallel circumferentially extending hanger sidewall ridges are located on the hanger sidewall. Each of the hanger sidewall ridges have upper and lower flanks that converge to a crest. Hanger sidewall bands are located between adjacent ones of the hanger sidewall ridges. A metal seal ring has an outer seal surface in metal-to-metal sealing engagement with the wellhead housing sidewall and an inner seal surface in metal-to-metal sealing engagement with the hanger sidewall bands. Crests of the hanger sidewall ridges embed into the inner seal surface to restrict relative movement between the hanger and the seal ring. A recess extends through each of the hanger sidewall ridges from the upper flank to the lower flank to allow any fluid trapped between the hanger sidewall ridges to flow out.

Abstract: A blowout preventer (“BOP”) includes a housing comprising a vertical bore extending through the housing and ram cavities intersecting the bore and ram assemblies, each ram assembly movably positionable within a ram cavity. Each ram assembly includes a packer assembly that comprises an upper plate, a lower plate, an elastomeric body positioned between the upper plate and the lower plate and comprising elastomeric material, and a support member comprising an aperture and positioned between the upper plate and the lower plate to provide support to the ram assembly.

Abstract: A subsea drilling system with a subsea component controllable by a fluid supply source. The system includes a pressure dampener in fluid communication between the fluid supply source and the subsea component. The pressure dampener includes a body consisting of a dampener fluid flow path which consists of a volume and a biasing system. The biasing system includes a piston biased to an initial position, wherein the piston is configured to move from the initial position to expand the volume of the dampener fluid flow path and dampen a pressure surge received by the pressure dampener and wherein the biasing system is configured to contract the volume of the dampener fluid flow path by returning the piston toward the initial position after dampening the pressure surge.

Abstract: A fracturing system including a fracturing manifold. In one embodiment, the system includes a fracturing manifold coupled to a plurality of fracturing trees via a plurality of fluid conduits. Further, multiple fracturing trees of the plurality of fracturing trees can each be coupled to the fracturing manifold by only a single fluid conduit of the plurality of fluid conduits to allow each of the multiple fracturing trees to receive fracturing fluid from the fracturing manifold via its respective single fluid conduit. Additional systems, devices, and methods are also disclosed.

Abstract: An RCD includes a housing, a seal assembly package, and a seal tube assembly. The seal tube assembly includes a seal tube, a seal, a first bearing, and a second bearing. The seal is coupled between the first and second bearings. The first bearing includes a flow path between the interior of the seal tube and the annular space between the seal and the seal tube. The SAP includes an SAP outer body positioned within the housing and fluidly sealed thereto. The RCD may include a running tool coupled to the SAP having one or more grippers for engaging a tool string passing through the RCD.

Abstract: A method of lining a wellbore having a tubular string cemented therein includes: running a liner string into the wellbore using a workstring having a liner deployment assembly (LDA) latched to the liner string; hanging the liner string from the tubular string and setting a seal of the liner string against the tubular string; opening a crossover valve of the liner string located below the set seal; and pumping cement slurry through the open crossover valve and down an annulus formed between the liner string and the wellbore.

Abstract: A sealing system includes a packing element having a groove in a surface thereof. The packing element is adapted to form a double hump configuration upon compression. The sealing system may include a first ring member disposed a first end of the packing element, a second ring member is disposed at a second end of the packing element, a first seal ring is disposed laterally outward of the first ring member, and a second seal ring is disposed laterally outward of the second ring member. A first inner back-up ring is disposed laterally outward of the first seal ring. The first inner back-up ring includes slots. A first outer back-up ring is disposed adjacent the first inner back-up ring and includes slots, wherein that slots in the first outer back-up ring are offset from the slots in the first inner back-up ring.

Abstract: A safety valve system for use in a subterranean well can include a safety valve protector connected downstream of a safety valve, whereby when closed the safety valve protector reduces a flow rate through the safety valve and prevents displacement of an object through the safety valve protector to the safety valve. Another safety valve system can include a safety valve protector which, when closed, reduces a flow rate through a safety valve, and the safety valve protector closes in response to the flow rate through the safety valve being above a predetermined level. In another safety valve system, each of the safety valve protector and the safety valve comprises an actuator, the actuators being connected by a line, and a signal transmitted by the line causes the safety valve protector actuator to close the safety valve protector, and then causes the safety valve actuator to close the safety valve.

Abstract: A method of applying acid-wash to a subsea connection assembly, in particular a stabplate connection, in order to remove unwanted material such as marine growth and calcareous deposits. The method consists of inserting a plug, containing channels, into a central in a stabplate connection and injecting acid-wash through the plug. The plug may be carried by an operating tool arm of a remotely operated underwater vehicle (ROV).

Abstract: There is described a chemical injection system for a natural gas well. An instrument monitors the production of gas from the well and the flow of chemicals injected into the well. The instrument controls the on and off time of a chemical injection pump that is attached to a chemical injection tank. The control is based for certain chemicals such as a surfactant on the gas flow rate in the production piping. The user of the system inserts in the instrument the setpoints associated with the well's flow rate. These setpoints determine for a given flow rate the on time for the chemical injection pump. Other chemicals can also be injected into the well using the system and the injection for those chemicals may be based on other criteria such as temperature, water rate, oil rate or pipeline flow rate.

Abstract: A segregated flow mechanism of oil and water usually takes place in the presence of strong gravity forces in subsurface environments, having specific geometrical and petrophysical properties undergoing simultaneous flow of multiphase fluids. The segregated flow of oil and water is modeled as a two-layer reservoir system, based on the observed data. Accurate estimates or measures of the values of phase mobility of oil and water, in addition to the actual flow capacity of the formation are provided. Reliable reservoir characterizations and reserve estimations are provided based on the in-situ conditions of oil and water in the reservoir.

Abstract: Improved corrosion inhibitors for well brines include a phosphonate or salts thereof, and a gluconic acid or salts thereof. The inhibitors are normally injected downhole into the brines. The most preferred phosphonates are amine polyphosphonates, used in combination with alkali metal salts of gluconic acid.

Abstract: The invention belongs to the oil industry and can be used for enhanced oil recovery by formations under complicated mining and geological conditions. The method of repeated completion of the production formations by helicoid perforation includes perforation, which is performed by moving the perforator along well axis and simultaneously rotating it around its axis with making perforation channels, provided that the speeds of movement and rotation of the perforator are selected based on the condition that the perforation obtained as a result is a helicoid with creation an empty space in the processed formation.

Abstract: A containment apparatus for protecting a surrounding environment from leaks originating from a stuffing box is provided. In some embodiments, the containment apparatus utilizes a float switch to switch off a pump associated with the stuffing box when the level of a liquid in the vessel exceeds a predetermined level. The switch can communicate ultrasonically with a receiver that relays a message to a user. In some embodiments, the vessel comprises two half vessels that are lined by a metal frame along there mating edges.

Abstract: A thermal compensator for a motor seal, includes: a guide tube for receiving a shaft of the motor seal; a metallic bag disposed around the guide tube and having an expansion profile formed in at least a portion thereof to accommodate radial and circumferential expansion of the metallic bag; a pair of flanges attached to opposite ends of the metallic bag; and a pair of adapters fastened to the respective flanges and receiving respective ends of the guide tube.

Abstract: A process for recovering oil from an oil-bearing formation is disclosed comprising providing a first oil recovery formulation comprising a first surfactant able to create low interfacial tension with reservoir crude oil; injecting the first oil recovery formulation into the oil-bearing formation via an injection well (201); providing a second oil recovery formulation having a second surfactant with a higher solubility in water than the first formulation; injecting the second oil recovery formulation into the oil-bearing formation via the injection well; and producing oil to a production well (203).

Abstract: A process for the recovery of hydrocarbon such as bitumen/EHO from a hydrocarbon bearing formation in which are situated an upper injection well and a lower production well, the method comprising the steps: preheating an area around and between the wells by circulating hot solvent through the completed interval of each of the wells until sufficient hydraulic communication between both wells is achieved; injecting one or more hydrocarbon solvents into the upper injection well at or above critical temperature of the solvent or solvent mixture, thereby causing a mixture of hydrocarbon and solvent to flow by gravity drainage to the lower production well; and producing the hydrocarbon to the surface through the lower production well. A non-condensable gas may be injected into the solvent chamber created by the hydrocarbon solvent.

Abstract: Apparatuses, methods, and systems include rotary drilling a first segment of a wellbore by rotating a drill string with a top drive forming a part of a drilling rig apparatus for a first period of time; obtaining data from a sensor disposed about the drilling rig apparatus while rotary drilling for at least a part of the first period of time; and based on the data from the sensor, determining a proposed oscillation revolution amount for the drill string to reduce friction of the drill string in the downhole bore without changing the direction of a bottom hole assembly while slide drilling.

Abstract: Rock strength is estimated during drilling using a rate of penetration model or a modified mechanical specific energy models. The rock strength estimate can be used in conducting further drilling, for example by a drilling system. Drilling parameters may be altered as a result of determining rock strength, for example to avoid undesirable trending fractures, such as extensive vertical fractures.

Abstract: Methods for measuring wellbore gauge and dogleg severity are disclosed. The methods include deploying a downhole tool in a subterranean wellbore. The downhole tool includes first and second axially spaced stabilizers deployed on at least one tool body section coupled to a universal joint. The method for measuring wellbore gauge further includes measuring first and second axial directions of the tool body section when the universal joint is tilted in corresponding first and second cross-axial directions and processing the first and second measured axial directions to estimate the wellbore gauge. The method for measuring dogleg severity further includes measuring first and second tilt angles of the universal joint when the universal joint is tilted in corresponding first and second cross-axial directions and then processing the first and second measured tilt angles to estimate the dogleg severity.

Abstract: A data communications system and method for transmitting data over a string between a surface location and a sub-surface location in a well bore in which a load varying device at the sub-surface varies the mechanical load on the string to be indicative of the data and a load measuring apparatus at surface monitors the mechanical load on the string and decodes the data. Data transmission is described from a pump assembly through a sucker rod string. Embodiments of load varying devices using electrical generators, friction rollers and hydraulic and pneumatic brakes are also described.

Abstract: Methods, systems, and apparatuses for remote well logging. Methods include conducting, with a plurality of remote well operation control hosts operating on corresponding remote well logging data acquisition management systems, a well logging operation using a well logging system at a logging site, wherein the well logging system includes a conveyance device having disposed thereon a first logging instrument and a second logging instrument; operating the first logging instrument responsive to at least one well-logging command from a first remote well operation control host of the plurality; and operating the second logging instrument responsive to at least one well-logging command from a second remote well operation control host of the plurality different than the first. Methods include transmitting a virtual presence feed associated with a logging site supervisor from the logging site to at least one of the corresponding remote well logging data acquisition management systems.

Abstract: Methods, systems, devices, and products for estimating a parameter of interest of a downhole fluid in a borehole intersecting an earth formation. Apparatus include evanescent wave measurement instruments, which may include a substrate configured for contact with a downhole fluid such that at least a portion of the substrate is immersed in the downhole fluid; a waveguide formed in an interior of the substrate and having a configuration geometrically configured to generate an interaction between the downhole fluid and an evanescent wave arising from electromagnetic energy propagating in a segment of the waveguide; and a detector configured to generate measurement information indicative of the downhole fluid in response to electromagnetic signals received from the waveguide responsive to the interaction. The interaction may result in absorption of at least a portion of the electromagnetic energy propagating in the waveguide. The waveguide may be written in the substrate using laser pulses.

Abstract: A mudlogging device may consist of a housing that is positioned above a ground level and proximal a wellbore. The housing can have a first interferometer and a second interferometer that are connected to a common pathway. The duel interferometer configuration may allow a gas sample to be concurrently tested by the respective interferometers.

Abstract: A milling depth compensation system for milling rock determines a target position of a machine, an initial position of the work surface, and a target pose of the machine based on the target position of the machine and the initial position of the work surface. An actual pose of the machine is determined and differences between the actual pose and the target pose are used to determine a dynamic milling path of a milling tool. The dynamic milling path includes movement of the milling tool along a first path, a second path, and a third path. Command signals are generated to move the milling tool along the dynamic milling path.

Abstract: A construction layout for caverns of an underground nuclear power plant, including: two primary caverns accommodating nuclear reactor powerhouses, combined caverns, electric powerhouse caverns, pressure relief caverns, a first primary traffic tunnel, a second primary traffic tunnel, a third primary traffic tunnel, a top adit system, and a ground adit system. Each combined cavern is disposed on one side of each of the two primary caverns. Each electric powerhouse cavern and each pressure relief cavern are disposed on two sides of each of the two primary caverns perpendicular to the longitudinal direction of the mountain. Each electric powerhouse cavern is perpendicular to the longitudinal direction of the mountain. The first primary traffic tunnel and the third primary traffic tunnel are disposed along the longitudinal direction of the mountain on outer sides of the two combined caverns, respectively.

Abstract: This invention of a continuous motion revolving piston engine describes a machine comprising piston(s) fitted to rings that revolve around a stator circular base which has a cavity in which a disc fits to create a closed combustion compartment together with the casing. The disc has a disc cavity to allow the piston to pass. The rotation of the disc and piston are synchronized to allow the piston to pass through the disc cavity. As there are no reciprocating parts and optionally enables an oil free operation, it is more efficient and has cleaner exhaust than existing engines.

Abstract: Efficient energy storage is provided by using a working fluid flowing in a closed cycle including a ganged compressor and turbine, and capable of efficient heat exchange with heat storage fluids on a hot side of the system and on a cold side of the system. This system can operate as a heat engine by transferring heat from the hot side to the cold side to mechanically drive the turbine. The system can also operate as a refrigerator by mechanically driving the compressor to transfer heat from the cold side to the hot side. Heat exchange between the working fluid of the system and the heat storage fluids occurs in counter-flow heat exchangers. In a preferred approach, molten salt is the hot side heat storage fluid and water is the cold side heat storage fluid.

Abstract: A method for patching a damaged polymeric erosion coating (250) on a gas turbine engine component. The method comprises removing a portion of the coating around a damage site (200; 202; 204) and applying a pre-formed coating patch (220).

Abstract: Methods for remotely joining material a surface area of a component of a gas turbine engine are provided. The method can include inserting an integrated repair interface attached to a cable delivery system within a gas turbine engine; positioning a tip of the integrated repair interface adjacent to a defect defined within a surface of the component; temporarily attaching the tip adjacent to the defect within the surface of the component; and supplying a new material to the area to fill the defect.

Abstract: The present invention relates to a centrifugal pump, the impeller of which comprises a shroud (34) with at least one solid and rigid working vane (36), and at least one solid and rigid rear vane (38), the at least one working vane (36) having a leading edge region (46), a trailing edge region (48), a central region (C), a side edge, a pressure face (42) and a suction face (44), the at least one solid and rigid rear vane (38) having a trailing edge region, a side edge, a pressure face and a suction face. The trailing edge region (48) of the at least one working vane (36) is rounded by means of a rounding to have a thickness greater than that in the central region (C).

Abstract: A strut and IGV configuration in a gas turbine engine positioned at an upstream of a rotor includes a plurality of radial struts, for example for bearing engine loads, and a plurality of inlet guide vanes positioned axially spaced apart from the struts. The number of inlet guide vanes is greater than the number of struts. The struts are circumferentially aligned with the inlet guide vanes.

Abstract: A rotor blade main body includes multiple first composite sheet groups and multiple second composite sheet groups which are provided in a blade thickness direction. Each first composite sheet group includes multiple composite sheets which are stacked one on another from a blade thickness center side toward a dorsal surface. Each second composite sheet group includes multiple composite sheets which are stacked one on another from the blade thickness center side toward a ventral surface. A composite direction of orientation directions of fibers in the multiple composite sheets in each of the sheet groups inclines by 20 degrees to 45 degrees from a span direction.

Abstract: According to one embodiment of this disclosure a core includes a first end and a second end spaced generally opposite from the first end. The core further includes a stacking axis defined between the first end and second end and a first toroidal structure located between the first end and the second end. The first toroidal structure includes a first passage extending through the first toroidal structure in a first direction that is perpendicular to and passes through the stacking axis. The core also includes a second toroidal structure located between the first toroidal structure and the second end. The second toroidal structure includes a second passage extending through the second toroidal structure in a second direction. The first direction and the second direction are oriented along the stacking axis at a non-zero degree angle with respect to each other.

Abstract: A component is provided and comprises at least one wall comprising a first and a second surface. At least one film cooling hole extends through the wall between the first and second surfaces and has an outlet region at the second surface. The film cooling hole includes a first expansion section being a side diffusion portion and a second expansion section being a layback diffusion portion, wherein the side diffusion portion is upstream and spaced from the layback diffusion portion.

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.

Abstract: Gas turbine engine turbine blade assembly includes a hollow airfoil joined to blade root, dovetail slot heat shield bonded or attached to a bottom surface of the root, and a shield outlet from heat shield open to inlet apertures extending radially through a radially inner root end of the root. Heat shield may have body with legs extending upwardly from heat shield bottom, slanted open upstream end, and free ends of the legs longer than the heat shield bottom. Flanges may be located along free ends and bonded to bottom surface. Body, heat shield bottom and/or the legs may be rounded. Disk includes a plurality of dovetail slots formed in a rim, complimentary plurality of turbine blades removably retained in dovetail slots by the roots, slot bottoms of the dovetail slots extending circumferentially between disk posts in rim. Heat shield bottoms may be radially spaced apart the slot bottoms.