Abstract: There is provided a gap sub-assembly for electrically isolating an upstream portion of a drill string from a downstream portion of the drill string. The gap sub-assembly includes a first sub; a second sub; and a non-conductive isolation between the first sub and the second sub, the non-conductive isolation being interposed between respective shoulders of the first sub and the second sub and being interposed between respective threads of a male end of the first sub and a female end of the second sub, the non-conductive isolation comprising an insulative wrapping between at least the respective threads of the first and second subs, wherein connecting the female end of the second sub to the male end of the first sub over the insulative wrapping electrically isolates the respective threads of the first and second subs. A method for assembling such a gap sub-assembly is also provided.

Abstract: A washpipe assembly includes a seal stack including at least one packing ring adapted to seal between a washpipe and the seal housing; a packing spacer ring adapted to maintain spacing between the seal housing and the washpipe, and a guide bushing ring positioned between the packing spacer ring and the washpipe. The guide bushing ring is made from a softer material than the wash pipe such that any contact therebetween will avoid damage to the washpipe. Additionally, the inclusion of the guide bushing ring may allow the packing spacer ring to be offset further from the washpipe than otherwise allowable.

Abstract: The present invention discloses a method for obtaining a tensile armor configuration of a flexible conduit comprising the steps of mounting an end ring engaged with the terminal region of each wire of each tensile armor, defining an initial position, which axially displaces the end ring in opposite direction to a free end of the flexible conduit, from the initial position to an end position, so as to cause flexure in the wires of each tensile armor and securing the end ring in end position, to maintain the wires of each tensile armor flexed. The present invention also proposes a connector for a flexible conduit, said connector comprising an end ring engaged with the terminal region of each wire of each tensile armor and fixed in an end position so that the wires of each tensile armor are flexed.

Abstract: A drill string coupling device is positionable at a joint within a drill string assembly and, in particular, a drive shaft forming part of a drive unit and an adaptor or axially rearwardmost part of the drill string. The coupling device includes at least one sleeve that is axially locked at one of the drill string components by a plurality of engaging wedges that are positioned between the sleeve and the drill string component. A plurality of rotational stops project axially from the sleeve to engage with a second component of the drill string or an element attached to the second component to rotatably lock the two components of the drill string assembly and prevent independent rotation.

Abstract: A friction-reducing device for use in a well bore, the friction-reducing device being cylindrically shaped with a tapered and partially threaded upper section, cylindrical middle section, and tapered and partially threaded lower section. The middle section comprises a cylindrical outer surface, cylindrical inner surface, solid portion between the cylindrical outer surface and the cylindrical inner surface, and first plurality of friction-reducing units. The friction-reducing units are installed at equally-spaced angular intervals into ports within the solid portion of the middle section in a circular array that lies in a first plane that is perpendicular to a longitudinal axis of the cylindrical bore in the friction-reducing device. Each friction-reducing unit comprises a rear bearing seat, an array of miniature ball hearings, and a main ball bearing with a protruding portion that extends through the inner surface of the middle section into the cylindrical bore.

Abstract: The present invention is a reel apparatus, system and method of using same that may generally maintain constant tension on a reel umbilical.

Abstract: The present invention is a reel apparatus, system and method of using same that may utilize sensors and proximity sensors in determining the rotational direction of an offshore reel as a component of maintaining a constant tension and constant slippage setting on the umbilical of the offshore reel as the radius to the umbilical varies and the deployment direction is reversed.

Abstract: The present invention is a reel apparatus, system and method of using same that may utilize accelerometers for determining the rotational direction of an offshore reel as a component of maintaining a constant tension and constant slippage setting on the umbilical of the offshore reel as the radius to the umbilical varies and the deployment direction is reversed.

Abstract: The present invention is a computer controlled reel apparatus, system and method of using same that may generally maintain constant tension on a reel umbilical.

Abstract: The present invention relates generally to a Top Drive Pipe Spinner (TDPS). The TDPS is a tool that allows for the setting of casing without a specialized crew or any additional power source. By employing the weight of the existing top drive to set slips below the casing collar and on the pipe, the TDPS allows one casing to be threaded onto the next in a timely and efficient manner. The casing tongs of the TDPS use passive release weight to release the casing collar from the casing to allow for the successive insertion of another casing section. The top drive spins the TDPS and compresses the unit onto the casing, then lifts the unit and releases the casing when desired.

Abstract: A coiled tubing reel assembly has two rotatable coiled, tubing reels that jointly hold a single continuous length of coiled tubing coiled wound around both of the reels. A drive mechanism provides controlled rotation to the reels and a levelwind mechanism positions the coiled tubing on the reels during reel rotation. The coiled tubing reel assembly allows transportation of greater continuous lengths of coiled tubing while minimizing the bending stresses associated with coiling and uncoiling the coiled tubing from the reels. Use of two coiled tubing reels also allows the overall dimensions of the reels to be minimized to facilitate transportation.

Abstract: A drilling fluid conditioning system can include at least one drilling fluid conditioning device, and at least one heat transfer property sensor that outputs real time measurements of a heat transfer property of a drilling fluid that flows through the drilling fluid conditioning device. A method can include measuring a heat transfer property of a drilling fluid, and determining, based on the measured heat transfer property, an oil to water ratio of the drilling fluid. A well system can include a drilling fluid that circulates through a wellbore and a drilling fluid conditioning system, and the drilling fluid conditioning system including at least one drilling fluid conditioning device, and at least one thermal conductivity sensor that measures a thermal conductivity of the drilling fluid.

Abstract: A method and apparatus for removing metallic material from a circulating well fluid stream provides a treatment vessel that is divided into first and second sections. Each of the sections includes a magnetic field that can be in the form of one or more magnets. In one embodiment, multiple magnets are provided in each of the sections. Manifolds attach to an influent and to an effluent of the treatment vessel. Each manifold enables selective transfer of fluid to either of the selected sections. Similarly, discharge of circulating fluid can be from either of the sections via a discharge manifold. The treatment vessel enables continuous treatment by valving fluid flow so that only one section need be used at a time in order that the other section could be serviced for removing collected metallic material from the magnetic field or from the magnets.

Abstract: Traction for a downhole tractor in a wellbore. A downhole propulsion system can provide a first traction module; a second traction module; and a controller configured to compare a first input parameter representing operation of the first traction module with a second input parameter representing operation of the second traction module. The controller can adjust a first output parameter of the first traction module and/or a second output parameter of the second traction module based on an input representing slip of the first traction module relative to the second traction module.

Abstract: A pipe joint debris catching tool for oil and gas wells including a monolithic and integrally formed pipe joint having a central body portion, opposite female and male end connector portions and an enlarged outwardly extending tubular sleeve space between the male end connector and the central body portion and wherein guide blades are removably mounted with parallel grooves formed in an outer tubular wall of the tubular sleeve and which blade extend along a length of the central body portion but spaced therefrom.

Abstract: Methods to induce pressure transients in fluids for use in hydrocarbon recovery operations. Pressure transients are induced in a fluid by a collision process. The collision process employs a moving object that collides outside the fluid with a body that is in contact with the fluid inside a partly enclosed space. The pressure transients must be allowed to propagate in the fluid. The fluid may be one or more of the following group: primarily water, consolidation fluid, treatment fluid, cleaning fluid, drilling fluid, fracturing fluid and cement.

Abstract: A subsea chemical injection system has a subsea structure, a manifold connected by jumper to the subsea structure, a coiled tubing, a disconnect mechanism affixed to the coiled tubing, and a hose extending from the disconnect mechanism to the manifold such that the chemical flowing through the coil tubing can selectively flow through the disconnect mechanism and through the hose to the subsea structure. The disconnect mechanism is adapted to selectively release from the hose. The disconnect mechanism has a connector affixed thereto. A hydraulic fluid supply is connected to the connector so as to selectively release the connector from the hose. Control lines can extend from a surface location to a control module and the disconnect mechanism for selectively delivering for receiving signals from the subsea structure.

Abstract: In order to overcome the limitation of being able to utilize a limited number of sliding sleeves with progressively more restrictive internal diameters in a particular wellbore when selectively opening the sliding sleeve or tool with progressively smaller balls or darts, an indexing dart may be utilized. A wellbore dart or pill is provided such that each time the dart passes through a downhole tool having a seat and externally extending finger is forced radially inward into the dart. As the finger moves inward to its depressed position, the finger moves a ball or other placeholder from a first position to a second position. When the ball is moved to the second position it may be released into the interior of the wellbore or it may be released into a chamber in the tool. In any event the ball is moved to a second position such that it may not return to the first position when the finger returns from its depressed position to its extended position.

Abstract: A downhole tool system includes a base tubular that includes a bore therethrough; a centralizer positioned to ride on the base tubular, the centralizer expandable to contact a wellbore wall and adjust a location of the downhole tool system relative to the wellbore wall based on a first fluid pressure supplied through the bore; and a liner top assembly positioned to ride on the base tubular, the liner top assembly including a wellbore liner and a pack-off element, the pack-off element expandable to at least partially seal a liner top of the wellbore liner to the wellbore wall based on a second fluid pressure supplied through the bore.

Abstract: A liner assembly tool includes a base tubular that includes a bore therethrough; a wellbore liner that includes a liner top and is coupled to the base tubular; a pack-off element radially positioned between the base tubular and the wellbore liner to ride on the base tubular; and a wedge positioned to ride on the base tubular and expand the pack-off element to at least partially seal the liner top to a wellbore wall based on a particular fluid pressure supplied through the bore.

Abstract: An exemplary downhole system includes a completion string positioned within a wellbore and providing at least an upper seal bore and a downhole device that includes a sliding sleeve. A service tool is extendable within the completion string and includes a shifting tool assembly and provides a mandrel, a shifting tool coupled to the mandrel, and upper equalization seals arranged on the mandrel and sealingly engageable with the upper seal bore. The shifting tool is engageable with the sliding sleeve to move the downhole device at least partially between a closed position, where a pressure differential between a subterranean formation and an interior of the completion string is assumed by primary sealing elements of the downhole device, and an open position, where the pressure differential is assumed by at least the upper equalization seals.

Abstract: A dual barrier system is provided to withstand pressure differentials well above those of the check valves in a float shoe used to allow circulation of a bottom hole assembly on the way to a desired depth. The bottom hole assembly can have screens and an internal wash pipe that pushes a sleeve to hold open a lower flapper for running in. The wash pipe also holds open an upper flapper that has opposed orientation to facilitate circulation when running in. Once on location an annulus packer closes off the producing zones where the screens are located from a lower zone that can have higher pressures. A high pressure packer is set against the shoe track and the wash pipe is retracted through this packer. Retracting the wash pipe allows closure of both flappers. Flow is blocked in opposed directions by the flappers and packer in the shoe track.

Abstract: A downhole tool, such as a sliding sleeve, is operable with pressure applied against one of a plurality of plugs deployed in the tool. A sleeve can engage the deployed plugs and can move with the engagement. The sleeve extends in an absence of external support and releases the engaged plug. However, an indexing mechanism is operable between the sleeve and an insert in the tool. The indexing mechanism moves with the sleeve in response to the engagement with the deployed plugs and counts those engagements. In response to a predetermined count, the indexing mechanism forms the external support of the one deployed plug engaged in the sleeve and moves the insert with the pressure applied against the one deployed plug, which is engaged in the sleeve and supported by the indexing mechanism. For example, the insert can move open in the tool relative to a flow port communicating outside the tool.

Abstract: The present invention provides wellbore cleaning tool and method featuring a wiper assembly which allows fluid to bypass the tool in one direction while diverting the well fluid through a filter screen in another direction. This may be achieved by either circulation of the fluid in the wellbore or by moving the tool relative to the fluid in the wellbore. The wiper assembly includes multiple groups or series of wiper elements wherein one petal shaped element aligns with a slot to form a seal when the tool body is retrieved from the well.

Abstract: A single line stab uses internal threading that allows a remotely operated vehicle (ROV) to mechanically mate up the stab and receptacle without the use of additional tooling. The use of a single coupler allows for a compact stab instead of the large junction plates that are currently used. Can be used to hydraulically control valves, inject fluid, or to sample fluids sub sea.

Abstract: A method for completing a wellbore extending through a subterranean formation may include installing a sandface completion assembly in the wellbore; pumping a solids free fluid comprising chemical precursors into an annulus formed between the subterranean formation and the sandface completion assembly; triggering and/or controlling chemical reaction between the chemical precursors to form a plurality of solid particles in the annulus.

Abstract: A wellscreen assembly has first and second screen joints connected together and has at least first and second adjoining tubes with opposed ends separated by a gap from one another. At least one jumper tube has first and second tubulars and fits in the gap between the adjoining tubes. The first tubular has a first end connectable to one of the opposed ends, while the second tubular has a second end connectable to another of the opposed ends. The second tubular is telescopically connected to the first tubular, and a biasing element biases the first and second tubulars away from one another. The first and second tubulars are operable between (i) a retracted condition retracting the first and second ends from the opposed ends and (ii) an extended condition extending the first and second ends to the opposed ends of the adjoining tubes.

Abstract: An apparatus for selling a liner in a wellbore that includes a setting tool attached to a work string. The setting tool includes a stretching mandrel and a liner top releasably attached to the setting tool. The liner top includes banded elastomer sheaths positioned in multiple locations along its length. The apparatus may also include a roller screw, operatively attached to the setting tool, so that a rotational movement imparted to the work string causes a forward, rotational movement of the stretching mandrel and engages the stretching mandrel with an inner portion of the liner top so that a protuberance is formed on the inner portion of the liner top and a groove is formed on an outer surface of the liner top.

Abstract: A liner having an outer surface coated with a fluid absorbing coating is cladded to a tubing string by inserting the folded liner into the tubing string and then unfolding the liner against the tubing string. The liner may be a long single thin foil corrosion resistant liner coated with a sticky glue and a hygroscopic and/or other fluid absorbing coating to absorb fluid pockets trapped between the tubing and liner and inhibit corrosion and leakage of, the elongate tubing string.

Abstract: A method of simultaneously injecting a proppant and an acidic well treatment fluid into a subterranean formation is described. The method includes pumping the acidic fluid into the formation while simultaneously pumping a slurry of the proppant in a carrier fluid containing one or more friction reducing agents. The acidic fluid stream and the proppant slurry stream mix before entering the formation and are pumped at approximately equal rates. Also described is a system for simultaneously pumping the acidic fluid and the proppant slurry into the formation.

Abstract: A dedicated borehole for an ESP or artificial lift mechanism communicates with a sump or wellbore to collect liquids and/or condensate from one or more other bores where there can be laterals into a producing formation. If the ESP or artificial lift mechanism needs to be replaced the dedicated bore with the ESP or artificial lift mechanism can be closed off and the ESP or artificial lift mechanism removed without taking out the main bore or bores connected to the sump or wellbore. Those bores can continue to produce gas as liquids and/or condensate accumulate in the sump, sumps or wellbore. When the ESP or artificial lift mechanism is replaced the liquid can be pumped to surface without interruption of the gas production.

Abstract: A method for drilling, comprising receiving, by a surface steerable system coupled to a drilling rig, BHA information from a rotary steerable bottom hole assembly (BHA) located in a borehole, calculating, by the surface steerable system, torsional and spatial forces acting on the rotary steerable BHA at a first location of the rotary steerable BHA with respect to a target drilling path responsive to the BHA information, calculating, by the surface steerable system, a first vector to create a convergence path from the first location of the rotary steerable BHA to the target drilling path that accounts for the torsional and the spatial forces acting on the rotary steerable BHA, causing, by the surface steerable system, at least one drilling parameter to be modified in order to alter a drilling direction of the rotary steerable BHA based on the calculated first vector, transmitting the at least one drilling parameter to the drilling rig to target the rotary steerable BHA in accordance with the first vector, and

Abstract: Disclosed embodiments include systems and methods for estimating real-time bit forces experienced on a drill bit and decoupling bit force disturbances. Real-time bit forces can be estimated based on bit force observers using measurements from downhole sensor subs. Model-based observers that adopted to estimate the bit force from downhole sensor sub measurements. Strain and torque measurements as measured by the sensor subs are used to estimate bit force and bit torque. These measurements can be observed using an effective observer design with the estimated bit force and bit torque based on sensor sub measurements to track the real bit force and bit torque. Observations of estimated bit forces and identified bit force disturbances can be used perform drilling dynamics modeling and identify the occurrence of negative drilling events.

Abstract: A coiled tubing deployment system includes an offshore rig having a reel positioned thereon and coiled tubing wound on the reel. A guide arch is positioned on the offshore rig to receive the coiled tubing from the reel, and a tubing guide receives the coiled tubing from the guide arch and directs the coiled tubing into water. A depth counter measures a length of the coiled tubing deployed from the reel and generate one or more length measurement signals, and a set of bend sensors is positioned on the tubing guide to measure real-time strain assumed by the coiled tubing as deployed into the water and thereby generate one or more bend sensor signals. A data acquisition system receives the length measurement signals and the bend sensor signals and provides an output signal indicative of real-time bending fatigue of the coiled tubing at select locations along the coiled tubing.

Abstract: A pressure test and actuation tool includes a housing; an insert disposed in operable communication with the housing. A metering head initially in sealed relation to both the housing and insert. A damper relief shoulder operably positioned relative to the metering head to initially support the metering head in sealed relationship with the housing and the insert and movable to unsupport the metering head defeating the sealed relationship with the housing and the insert. A method actuating a tool.

Abstract: Methods and a system for communication between the well logging surface equipment and downhole tools. A well logging communication system comprised of a surface modem, one or more downhole modems for communication to the surface through one or more signal channels of the wireline. A system with zero, one or multiple downhole tool buses.

Abstract: A receiver for a dual telemetry measurement while drilling (MWD) system and method for operating same are provided. The receiver includes a mud pulse receiver module for receiving a first signal sent using mud pulse telemetry via a pressure transducer configured to detect mud pulses transmitted through a mud column in a drill string; an electromagnetic (EM) receiver module for receiving a second signal sent using EM telemetry via the drill string and a formation; and a processer for obtaining the first signal when operating in a mud pulse mode and the second signal when operating in an EM mode and having MWD data displayed at a surface system.

Abstract: A system of formation sampling while drilling, comprising: a suction pup joint provided to pump out and clean the formation fluid; a sampling pup joint provided to sample and store the formation fluid; a setting pup joint provided between the suction pup joint and the sampling pup joint and provided to establish a fluid channel between the formation fluid and the suction pup joint, the sampling pup joint; and an electrohydraulic high voltage connection device provided between the setting pup joint and the sampling pup joint. The embodiments of the present invention can be applied in the field of formation exploration technology, the function of storing the formation sample in the process of logging while drilling can be accomplished and the current logging instrument can be effectively optimized, the universality and precision of the current logging function can be effectively improved according to the embodiments of the present invention.

Abstract: An improved drive pin retention system for mining chains is disclosed, including several embodiments. The drive pin retention system further decreases the chance that the chain can break due to sheared dowel pins.

Abstract: A mining machine includes a chassis, a cutting assembly coupled to the chassis, and a spray arm coupled to the chassis and positioned proximate the cutting assembly. The chassis includes a first end, a second end, and a chassis axis extending between the first end and the second end. The chassis is movable in a direction parallel to the chassis axis. The cutting assembly includes an arm and a rotatable cutting drum having a plurality of cutting elements. The spray arm includes a first portion, a second portion pivotably coupled to the first portion, and at least one spray nozzle for emitting a fluid spray in a region adjacent the cutting assembly. The first portion is coupled to the chassis and extends away from the chassis along a spray arm axis. The second portion is pivotable relative to the first portion about a wrist axis.

Abstract: Systems and methods are described for monitoring a condition of a mine roof using a longwall mining system. A plurality of powered roof supports is controlled to apply an adjustable support pressure on a mine roof. A condition of the mine roof is monitored based on the adjustable support pressure applied to the roof by a respective actuator of each powered roof support. In some implementations, the condition of the mine roof is monitored by generating and analyzing a graphical pressure map based on the adjustable support pressure applied by each powered roof support and a relative position of a shearer moving across the mine face. In some implementations, roof collapse events are detected based on temporally similar changes in the adjustable support pressure applied by multiple adjacent powered roof supports as indicated by the graphical pressure map.

Abstract: A rotor component for a rotor assembly of a fluid energy machine, particularly of a gas turbine, a steam turbine, a compressor or the like, wherein the rotor component is at least partly made of a material susceptible to corrosion and/or oxidation and can be arranged concentrically to a rotation axis of the rotor assembly. The rotor component includes a circular surface for checking concentricity of the rotor component with respect to the rotation axis. The rotor component includes at least one additional circular surface for checking concentricity of the rotor component with respect to the rotation axis, wherein the additional circular surface is coated with a corrosion and/or oxidation protection coating.

Abstract: The invention relates to a turbomachine (30) comprising: a compressor stage and a turbine stage, each stage comprising at least one disk (42); and a tubular shaft (31) sleeve (33) extending along the axis (32) of the turbomachine, wherein the sleeve (33) comprises at least one tab (40) extending from an outer radial surface (41) of the sleeve and facing the disk (42), the tab (40) being designed to come into contact with the disk (42) when the sleeve (33) is in rotation about the axis (32) of the turbomachine.

Abstract: A method of designing a gas turbine engine comprises the steps of including a fan section with a fan. A turbine section is included having a first turbine and a second turbine. A gear reduction is included between the fan and the first turbine, the gear reduction being configured to receive an input from the first turbine and to turn the fan at a lower speed than the first turbine in operation. The first turbine is designed to include a number of turbine blades in each of a plurality of rows of the first turbine, the first turbine blades operating at least some of the time at a rotational speed, and the number of blades and the rotational speed being such that the following formula holds true for at least one of the blade rows of the first turbine: (number of blades×speed)/60?5500.

Abstract: Disclosed is a method for manufacturing a blading member assembly for a fluid flow machine, wherein the blading member assembly includes at least one airfoil member and one platform member. The method includes manufacturing a platform member blank, manufacturing an airfoil member blank, and processing at least one of said blanks thus obtaining the at least one airfoil member and at least one platform member, and subsequently joining the at least one platform member and the at least one airfoil member, thus providing the blading member assembly. The method, for instance, provides larger flexibility in arranging cooling openings.

Abstract: A hot gas path component includes a substrate having an outer surface and an inner surface. The inner surface defines an interior space. The outer surface defines a pressure side surface and a suction side surface. The pressure and suction side surfaces are joined together at a leading edge and at a trailing edge. A first cooling passage is formed in the suction side surface of the substrate. It is coupled in flow communication to the interior space. A second cooling passage, separate from the first cooling passage, is formed in the pressure side surface. The second cooling passage is coupled in flow communication to the interior space. A cover is disposed over at least a portion of the first and second cooling passages. The interior space channels a cooling fluid to the first and second cooling passages, which channel the cooling fluid therethrough to remove heat from the component.

Abstract: A cooling system (10) for a turbine airfoil (12) of a gas turbine engine, wherein the airfoil (12) has a bowed configuration is disclosed. The airfoil (12) may be configured such that the leading edge (16) or trailing edge (18), or both, may have midsections that are positioned further upstream than outer ends of the leading and trailing edges (16, 18). One or more cooling channels (28) of the cooling system (10) may have a larger cross-sectional area proximate to an end of the airfoil (12) than at a midspan location. One or more cooling channels (28) may have one or more corner blockers (30) that extend chordwise in the cooling channel (28) and extend from a corner (54) toward a centerline axis (34), thereby reducing a cross-sectional area of the cooling channel (28). The corner blockers (30) may be positioned within the cooling system (10) to maintain the flow of cooling fluids through the airfoil (12) within desired design parameters.

Abstract: An airfoil for a gas turbine engine is disclosed. The airfoil may include a first side, and a second side opposite the first side. The first side and the second side may extend axially from a leading edge to a trailing edge and radially from a base to a tip. The tip may include an oblique surface between the first side and the second side.

Abstract: A method is provided for modifying an airfoil shroud located at a tip of a blade of an airfoil, the airfoil shroud having a first end edge, a second end edge, a leading edge, and a trailing edge. The method includes locating a reference location in the first end edge of the airfoil shroud, the reference location including a portion of a seal rail extending circumferentially from a radially outer surface of the airfoil shroud, and a fillet extending from the radially outer surface and positioned directly adjacent to the seal rail. The method further includes forming a relief cut in the seal rail and fillet without performing a weld process on the airfoil shroud to remove the reference location, and installing the airfoil shroud in a turbomachine directly following forming the relief cut, wherein modifying the airfoil shroud is complete following forming the relief cut.

Abstract: Engineered groove features (EGFs) are formed within thermal barrier coatings (TBCs) of turbine engine components. The EGFs are advantageously aligned with likely stress zones within the TBC or randomly aligned in a convenient two-dimensional or polygonal planform pattern on the TBC surface and into the TBC layer. The EGFs localize thermal stress- or foreign object damage (FOD)-induced crack propagation within the TBC that might otherwise allow excessive TBC spallation and subsequent thermal exposure damage to the turbine component underlying substrate. Propagation of a crack is arrested when it reaches an EGF, so that it does not cross over the groove to otherwise undamaged zones of the TBC layer. In some embodiments, the EGFs are combined with engineered surface features (ESFs) that are formed in the component substrate or within intermediate layers applied between the substrate and the TBC.