Abstract: An electronic control system comprises a first tubular handling tool, a sensor, and a controller. The controller is configured to control actuation of the first tubular handling tool in response to an electronic signal received from the sensor that corresponds to an operational characteristic of the first tubular handling tool. The electronic control system functions as an electronic interlock system to prevent mishandling of a tubular. A method of controlling a tubular handling tool comprises measuring an operational characteristic of the tubular handling tool, communicating the operational characteristic to a controller in the form of an electronic signal, and using the controller to control actuation of the tubular handling tool in response to the measured operational characteristic.

Abstract: An automated pipe tripping apparatus includes an outer frame and an inner frame. The inner frame includes a tripping slips and iron roughneck. The automated pipe tripping apparatus may, in concert with an elevator and drawworks, trip in a tubular string in a continuous motion. The tripping slips and iron roughneck, along with the inner frame, may travel vertically within the outer frame. The weight of the tubular string is transferred between the tripping slips and the elevator. The iron roughneck may make up or break out threaded connections between tubular segments, the upper tubular segment supported by the elevator and the lower by the tripping slips. An automated pipe handling apparatus may remove or supply sections of pipe from or to the elevator. A control system may control both the automated pipe tripping apparatus and the elevator and drawworks.

Abstract: A processing system for separating solids from used drilling fluids to produce cleaned drilling fluids includes a cleaned drilling fluid tank and a filtering unit having an inlet container and a separating mechanism. An example filtering unit mounts to a top surface of the cleaned drilling fluids tank while a portion of the inlet container extends beneath the top surface. Certain types of flow lines may extend through the fluid tank to the portion of the inlet container. Certain types of flow lines may have multiple flow line inlets. Certain types of flow lines may have flow rate sensor arrangements.

Abstract: A managed pressure drilling (MPD) operation may use an inverse model in conjunction with a hydraulic model and real-time drilling conditions and parameters as inputs to determine a wellhead pressure set point corresponding to a desired bottomhole pressure. For example, while drilling a wellbore penetrating a subterranean formation with a drilling system, measured data including a wellhead pressure may be acquired. A model may then be executed that applies a hydraulic model to an a priori model estimate vector to produce predicted data; converts the measured data to a measured data vector; applies a randomized maximum likelihood algorithm to the a priori model estimate vector, the predicted data, and the measured data vector to produce an a posterioiri model estimates; and applies the hydraulic model to the a posterioiri model estimates to produce an a posteriori prediction and a calculated wellhead pressure set point corresponding to a desired bottomhole pressure.

Abstract: A subsea filler line system adapted to transport different types of fluids in separate batches through one single supply conduit, or flexible line, from the sea surface to respective dedicated storage tanks, or vessels, installed on the seabed, is described. The system includes respective valves and control systems to operate the subsea filler line system. The subsea filler line system includes at least two pigs adapted to be pushed by the transported fluid through said supply conduit, or flexible line, which pigs further provide a barrier between the respective fluids in front of and behind each pig, thus being able to define respective fluid batches between following pigs, each fluid batch being directed by means of valves through an inlet into said supply conduit and an outlet from said supply conduit and further on to the respective dedicated storage tanks, or vessels, on the seabed. A method for transporting various fluids in separate batches through a master flow conduit is also disclosed.

Abstract: Coring tools including a core tube assembly; a carrier chamber defined within the core tube assembly for storing one or more core samples drilled from a downhole formation having a wellbore fluid therein, wherein the wellbore fluid has a wellbore fluid density; a non-hydrocarbon, non-reactive heavy weight fluid (“HWF”) present within the carrier chamber, the HWF exhibiting a HWF density of about 2 pounds per gallon greater than the wellbore fluid density; a pressure housing cover selectively rotatable between (1) an open position, where the one or more core samples are able to be inserted into the carrier chamber, and (2) a closed position, where the carrier chamber is sealed; and a cover activation mechanism coupled to the core tube assembly and operable to move the pressure housing cover between the closed position and the open position.

Abstract: A floating, offshore drilling and/or production platform is equipped with a rail-mounted transport system that can be positioned at a plurality of selected positions over the well bay of the vessel. The transport system can move a drilling riser with a drilling riser tensioner system and a blowout preventer from one drilling location to another without removing them from the well bay of the vessel. Using the transport system, the drilling riser is lifted just clear of a first well head and positioned over an adjacent, second well head using guidelines. The transport system may then move the upper end of the drilling riser (together with its attached tensioner and BOP) to a second drilling location. A dummy wellhead may be provided on the seafloor in order to secure the lower end of the drilling riser without removing it from the sea while production risers are being installed.

Abstract: A subsea connection system for connecting to a hub has a body with an interior passageway suitable for allowing fluids to flow therethrough, a collet having a plurality of collet segments that are movable between a locked position and an unlocked position, an outer sleeve overlying the collet, and a translator cooperative at the outer sleeve so as to move the outer sleeve between a first position and a second position. The plurality of collet segments are in the unlocked position when the outer sleeve is in the first position. The plurality of collet segments are in the locked position when the outer sleeve is in the second position. The locked position is adapted to secure the body in connection with the hub.

Abstract: An apparatus for distributing fluids to a well. In one embodiment, the apparatus includes a well stimulation fluid delivery system having an intake connection for receiving well stimulation fluid and a first conduit configured to route the well stimulation fluid from the intake connection to multiple outlet connections configured to be coupled to pumps for increasing the pressure of the well stimulation fluid. A second conduit of the apparatus is configured to receive the well stimulation fluid from the pumps, via multiple inlet connections configured to be coupled to the pumps, and to route the well stimulation fluid to a discharge connection. The apparatus also includes individual skids including platforms on which fluid conduit segments are mounted. The individual skids are coupled to one another via their mounted fluid conduit segments to form the first conduit and the second conduit. Additional systems, devices, and methods are also disclosed.

Abstract: A system, in certain embodiments, includes a horizontal fracturing tree. The horizontal fracturing tree includes a first hydraulic fracturing bore configured to flow a first fluid, wherein the first hydraulic fracturing bore extends along a first horizontal axis, and the first horizontal axis is generally perpendicular to a vertical axis of a wellhead.

Abstract: The invention provides a flow control valve for a subsea hydrocarbon production system and a method of use. The flow control valve comprises an inlet configured to be in fluid communication to an injection fluid conduit and an outlet configured to be in fluid communication with a subsea flow system. A flow control mechanism is disposed in a flow path between the inlet and the outlet and is arranged to adjust a flow rate through the flow path. The flow control mechanism is configured to automatically adjust the flow rate of injection fluid through the flow path according to a pressure differential between fluid pressure at the inlet and fluid pressure at the outlet. Adjustment may be self-regulating, or may be controlled by a hydraulic control circuit.

Abstract: The isolation tool works at depth in the bore of a pipe whose upper end is to be severed and replaced. The tool isolates the lower pipe bore from the upper bore so that flammable downhole fluid is prevented from reaching a welding site along the pipe wall. The tool incorporates: means for establishing a pair of axially spaced apart annular seals engaging the pipe inner surface; means for venting downhole fluid to ground surface; and means for monitoring for seal leakage. The tool is primarily mechanical in nature. It finds use in connection with off-shore platform riser renewal operations.

Abstract: A packer comprising a mandrel having a radially directed port disposed therein and a passageway axially disposed therein and a packer element disposed around a portion of the mandrel. The packer further includes a housing disposed around a portion of the mandrel creating an annulus area between the mandrel and the housing, the housing is disposed adjacent to the packer element to squeeze the packer element and axially expand the annulus area when fluid flows through the radially directed port and into the annulus area above a fluid pressure threshold. The packer can be included in a downhole assembly having an upper packer and a lower packer. A method of using the packer includes placing the packer into a wellbore to seal one zone from another and pumping fluid into the packer to set the packer element against a casing in the wellbore. A method of using the assembly that incorporates the upper packer and the lower packer is also described.

Abstract: A downhole apparatus for use in a tubular include a mandrel, a first slip, a cone, and a seal element. The mandrel, which can be permanent or temporary, has a first end shoulder. The first slip is disposed on the mandrel adjacent the first end shoulder, and the cone is disposed on the mandrel adjacent the first slip. The cone is movable relative to the first end shoulder to engage the first slip toward the tubular. The seal element is disposed on the mandrel adjacent the cone. At least a portion of the seal element is composed of a dissolvable metallic material and is expandable outward from the mandrel. The expanded portion of the seal element forms a metal seal against the tubular and seals off fluid communication in the annular space between the seal element and the tubular.

Abstract: An isolation of part of a well, which includes a pipe provided, along its external face, with a first external sleeve, wherein the opposite ends are connected directly or indirectly to said external face of the pipe. The pipe, first external sleeve and its ends together delimit an annular space, the wall of said pipe exhibiting at least one opening which allows it to communicate with said space, this sleeve being likely to expand and to be applied tightly against the well over an intermediate part of its length. The device also includes on the one hand, a second internal sleeve, which extends between said pipe and the first sleeve, its ends being also connected directly or indirectly to the external face of said pipe and, on the other hand, at least one communication passage between the exterior of the first sleeve and said space.

Abstract: A fluid pressure operated actuator assembly comprising a tubular body (110) having a wall, with an interior surface and an exterior surface and enclosing a main passage (112) which extends generally parallel to a longitudinal axis of the tubular body, an actuator (118) located in and movable along the main passage, a first direction chamber (138a) formed between the wall of the tubular body and the actuator, and at least one second direction chamber (138b, c) formed between the tubular body and the actuator, wherein the assembly is configured such that when the pressure of fluid in the first direction chamber exceeds the pressure of fluid in the or each second direction chamber by a predetermined amount, the pressure of fluid in the first direction chamber exerts a force on the actuator which acts to push the actuator in a first direction relative to the tubular body, and when the pressure of fluid in the or at least one of the second direction chamber(s) exceeds the pressure of fluid in the first direction c

Abstract: A device for removing rotating head rubbers from drill pipe comprising a base member, vertical shaft, lower pipe attachment bracket, left arm, right arm, diagonal shaft and upper pipe attachment member. Proximal ends of the left and right arms are welded to a top end of the vertical shaft, and the left and right arms lie in the same horizontal plane. Proximal ends of the left and right arms are welded together and distal ends of the left and right arms are separated so that the arms form a V-shaped fork. The diagonal shaft is welded to the top end of the vertical shaft at an upward angle of approximately 45 degrees. The upper pipe attachment member is removably inserted into a distal end of the diagonal shaft.

Abstract: The present disclosure relates to passive flow control devices or FCDs and modeling methods applicable to same. In particular, a new method to extrapolate the value of a reference FRR tool to other tools with the same architecture, but different ratings. Instead of scaling the output of the model, the data of the available characterizations is used to extrapolate what the characterization results would be to the different FRR. This estimated data set is then used to fit a new model for the uncharacterized FRR tool.

Abstract: Embodiments relate generally to gimbal bearings for installation of a riser string. Gimbal bearing embodiments comprise a top ring and a bottom ring, with a plurality of high capacity laminate bearings located therebetween, the high capacity laminate bearings comprising at least one of natural rubber and a marker layer. Each high caparity laminate bearing might comprise alternating layers of steel shims and elastomeric elements bonded together via adhesive. Embodiment designs provide for improved gimbal bearing characteristics, which may improve the effective lifespan of such gimbal bearings.

Abstract: A system for conveying fluids at a subsea location includes a module having a flow line formed of plurality of linear sections. At least two of the sections have a geometrically parallel arrangement. The module includes an inlet supplying fluid to the flow line and an outlet receiving fluid from the flow line.

Abstract: Screen sections have opposed open ends near the threaded connection of a base pipe and on opposed ends. The base pipes have premium threads for connection. A shroud is placed over the premium bases pipe connection that spans from one open ended screen section to another that is adjacent. Collectively a long annular space is created under the screens and alternating shrouds with access to within the base pipes provided preferably at opposed ends. The valve on one end takes returns during gravel packing and the other takes production to the surface.

Abstract: A perforating gun has shaped charges that can generate a high-pressure gas. A valve sub connects to the perforating gun and a reservoir sub connects to the valve sub. The valve sub has an enclosure with a port. A mandrel in the enclosure has a piston head and a fluid path extending at least partially through the mandrel. A sleeve is slidably mounted on the mandrel and selectively blocks fluid flow through the port. A pressure chamber in the sleeve receives the generated high-pressure gas via the fluid path. The sleeve slides toward the perforating gun after a predetermined pressure is created by the generated high-pressure gas in the pressure chamber. The reservoir sub may have at least one chamber in fluid communication with the interior of the valve sub.

Abstract: The present invention relates to a method and apparatus for firing and propelling one or more projectiles into an earthen or subterranean formation for the purpose of stimulating and enhancing communication between a well bore and said formation.

Abstract: A technique facilitates controlled detonation in well environments and other types of environments. Electronics for controlling detonation of a pellet of explosive material are mounted on a structure, such as a circuit board. The pellet is operatively coupled with the electronics and positioned to extend outwardly from the structure. Another explosive component is arranged across the pellet at a predetermined angle, e.g. a right angle, with respect to a longitudinal axis of the pellet. In well applications or other applications utilizing shaped charges, the explosive component may be coupled to the shaped charge via a detonator cord.

Abstract: The present invention relates to a downhole system for unloading a liquid of a well in an annulus between an intermediate casing and a production tubular metal structure.

Abstract: A well servicing fluid includes ingredients including a GLDA salt, a crosslinker, and a viscosifying agent that is not crosslinked by the crosslinker. A well treatment method includes forming a well servicing fluid with ingredients including a GLDA salt, a viscosifying agent, and a crosslinker, the GLDA salt containing a metal cation chelated with a GLDA anion. The well servicing fluid is inserted into a well in a formation. The method includes crosslinking the viscosifying agent and attaining a first viscosity of the well servicing fluid using the crosslinker. After the attaining of the first viscosity, viscosity of the well servicing fluid in the well is decreased to a second viscosity less than the first viscosity by using the GLDA anion. The GLDA salt may be a GLDA calcium salt and the crosslinker may be a zirconium crosslinker.

Abstract: The fracturing methods described in the present disclosure provide advantage over the current fracturing methods. The disclosed fracturing methods can change the fracture gradient of the downhole subterranean formation. For example, one or more of the fracture gradients of the low and high stress zones of the downhole subterranean formation can be changed. Furthermore, the methods of present disclosure, in relation to current practices, can decrease the extent and/or degree of fracturing within low stress downhole formations and increase the degree of fracturing within high stress formations.

Abstract: Systems and methods are provided for maintaining the performance and operational stability of an RF (radio frequency) antenna that is positioned in a hydrocarbon-bearing formation, for heating the formation using electromagnetic energy in the radio frequency range. Contaminants such as water or brine, metallic particulates and ionic or organic materials frequently occur in a wellbore being prepared for RF heating, or in an RF antenna installed in the wellbore. Prior to applying RF electrical energy to the formation, the antenna is decontaminated by circulating a preconditioning fluid through the antenna and recovering a spent fluid for treating and recycle. Decontamination is continued while the spent fluid from the antenna includes, but not limited to, water, metallic particles, ionic species, organic compounds contaminants, etc. An operational power level of radio frequency electrical energy is then applied to the decontaminated antenna for providing thermal energy to the hydrocarbon-bearing formation.

Abstract: Techniques for well testing include providing an amount of a chemical material to a location in a wellbore; reacting the chemical material to generate an exothermic chemical reaction at the location in the wellbore; and fracturing the formation by the exothermic chemical reaction.

Abstract: The present invention discloses a method and an apparatus for predicting performance profiles of multi-layered oil reservoirs, wherein the method comprises: dividing the multi-layered oil reservoirs into a plurality of blocks, and determining a reservoir type, formation factor Kh and an evaluated reserves of each layer in each block; selecting a block representing geologic features of the multi-layered oil reservoirs from the plurality of blocks as a representative block, to build a fine geological model of the representative block; building corresponding fine numerical simulation model according to the fine geological model of the representative block, and determining type curves of different reservoir types under different development strategies; determining a relation curve between Kh and well injection rate for injectors and a relation curve between Kh and well production rate for producers in the multi-layered oil reservoirs under different restrictive conditions; predicting performance of the multi-laye

Abstract: A method for evaluating inflow or outflow in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval density may be measured during static conditions or while drilling and may be further processed to compute a density of an inflow constituent in the annulus. Changes in the computed interval density with time may be used as an indicator of either an inflow event or an outflow event.

Abstract: This inventive method provides a novel way of modeling basins in planning the drilling of crude oil and natural gas wells by accounting for thermodynamic considerations in tracking the pore pressure of a location of interest. By plotting the energy gradients, heat flux, and thermal conductivity of the location of interest, the user can more accurately identify the location of the Top of Geopressure and additional pertinent information during the well drilling planning process that can reduce costs and increase the safety of the process.

Abstract: A method and system for evaluating both fluid type and fluid flow downhole by applying thermal energy in a flow of the fluid, and monitoring downstream temperature over time to generate a temperature profile. The type of fluid being evaluated can be determined by comparing the measured temperature profile to profiles over time of known fluids because these profiles depend upon these fluids' thermal diffusivities and flow rates. Further, stratified flow in a deviated wellbore can be analyzed by conducting the fluid evaluation at different radial locations in the flow stream so that the presence of water, liquid hydrocarbons, and gas can he identified. The system can include a pivoting arm that selectively spans the wellbore diameter, and which includes multiple thermal sources, each with corresponding thermal sensor, that are spaced along the arm. A frame can be provided for each of the sources and sensors, which is automatically self-oriented along the direction of fluid flow like a weather vane.

Abstract: According to some embodiments, a tie-bolt support assembly is provided which includes a support spring for engagement with both the tie-bolt and a rotor assembly to maintain a load path between the tie-bolt and the rotor assembly while also allowing for axial movement of the tie-bolt.

Abstract: A turbine 10 includes: a turbine rotor having a rotor main body including a hollow part into which a cooling fluid flows, and a plurality of rotor wheels arranged in an axial direction of the rotor main body and protruding from the rotor main body. A cooling-fluid introducing passage extending from the hollow part in a direction intersecting with the axial direction of the rotor main body is formed in the rotor main body so as to allow the cooling fluid in the hollow part to flow through the cooling-fluid introducing passage and then to flow around the rotor wheel to be conducted to the working-fluid flow passage. A flow-rate control plug regulating a flow rate of the cooling fluid flowing through the cooling-fluid introducing passage is disposed in the cooling-fluid introducing passage.

Abstract: A method and device for cooling a turboengine rotor. A blade member includes a platform having a hot gas side and a coolant side. An airfoil is on the platform hot gas side and a blade foot section is on the platform coolant side. The blade foot section includes a blade shank and a blade root. The blade shank extends from the platform coolant side and is interposed between the blade root and the platform coolant side. The blade root includes root fixation features and is received by a fixation feature of a rotor shaft. A first fluid flows along the rotor front face and into a cavity of the blade shank and a second fluid flows within the blade shank cavity. The first fluid flow is relatively colder than the second fluid flow and a combined shank cavity fluid flow is formed inside the blade shank cavity.

Abstract: An assembly for a gas turbine that engine includes a fan section. A turbine section is configured to drive the fan section. The turbine section includes a rotor hub with a rotor lug. A heat shield engages the rotor lug. The heat shield and the rotor lug define a cooling passage.

Abstract: A method for treating a field operated component is disclosed which includes providing the component including a ceramic matrix composite and removing a first portion of the component, forming a first exposed surface on the component. The method further includes providing a second portion including the composite, the second portion having a second exposed surface including a conformation adapted to mate with the first exposed surface. The second portion is positioned in association with the component so as to replace the first portion, and the second portion and the component are joined to form a treated component. Another method is disclosed wherein the component is a turbine component which further includes removing an environmental barrier coating from the component, arranging and conforming the first exposed surface and the second exposed surface to define a joint, and applying an environmental barrier coating to the treated component.

Abstract: A spiral turbine blade having at least one concave compartment that is rotatable by a moving fluid for the generation of electricity is provided. A spiral turbine blade is aligned so that the axis of rotation is generally parallel to the mean direction of a moving fluid. Attached to the intake-facing side of the at least one spiral turbine blade are concave compartments comprised of an intake void, interior space, and exit void. The concave compartments are oriented to capture an additional range of velocity imaginary vectors; specifically those aligned via vortex inducing elements, such as spiral depressions on a conical intake shroud, thereby augmenting the torque induced the spiral turbine blade, and thus improving the conversion efficiency and electrical energy output.

Abstract: A component for a gas turbine engine according to an exemplary aspect of the present disclosure includes, among other things, a platform having an outer surface and an inner surface that axially extend between a leading edge portion and a trailing edge portion. At least one augmentation feature is disposed on at least the leading edge portion or the trailing edge portion of the outer surface of the platform.

Abstract: A gas turbine engine component includes a structure having a wall that provides an exterior surface. A first cooling passage is arranged adjacent to and interiorly of the wall. A second cooling passage is arranged in the wall and provides a first fluid flow direction. A resupply channel is arranged in the wall and is fluidly interconnected to the second cooling passage. A resupply hole fluidly interconnects the first cooling passage and the resupply channel. The resupply channel is transverse relative to the second cooling passage to provide a second fluid flow direction that extends from the resupply hole to the second cooling passage.

Abstract: A vane includes a forward rib and an aft rib positioned axially aft of the forward rib. The vane also includes a middle rib positioned axially between the forward rib and the aft rib, such that the forward rib and the middle rib define a forward passage configured to receive a forward baffle and the middle rib and the aft rib define an aft passage configured to receive an aft baffle. The vane also includes an inner surface extending axially from the forward rib to the aft rib, being radially separated from the middle rib via a gap such that air can flow between the aft passage and the forward passage via the gap, and having a radially outward curve from the forward rib to the middle rib and having a radially inward curve from the middle rib to the aft rib.

Abstract: A steam turbine diaphragm nozzle segment, related assembly and steam turbine. Various embodiments include a steam turbine diaphragm nozzle segment having: a pair of opposing sidewalls; an airfoil extending between the pair of opposing sidewalls and integral with each of the pair of sidewalls, the airfoil having a single contact surface for directing a flow of working fluid through a flow channel; and a fill region integral with the airfoil and the pair of opposing sides, the fill region extending between the pair of opposing sides along an entirety of a length of the airfoil, the fill region for completely obstructing the flow of working fluid.

Abstract: The invention relates to a guide vane assembly of a turbomachine based on a modular structure, wherein the guide vane elements include at least an airfoil, an inner platform, an outer platform, wherein the guide vane airfoil and/or platforms have at its one ending provisions for connection of the guide vane elements among each other. The connections of the guide vane elements among each other are configured as a detachable, permanent or semi-permanent fixation with respect to the radial or quasi-radial extension of the airfoil compared to the rotor axis of the turbomachine. The assembling of the airfoil with respect to at least one platform is based on a force-fit and/or a form-fit connection, or on the use of a metallic and/or ceramic fitting surface, or on force closure means with a detachable, permanent or semi-permanent fixation.

Abstract: A stator device for a continuous-flow machine with a housing appliance and multiple guide vanes that are arranged in a circumferentially distributed manner at the housing appliance. The guide vanes are respectively embodied with a blade leaf and respectively at least one platform. At least in certain areas, the platforms form a surface of an annular channel through which working fluid flows during operation of the stator device, and are mounted so as to be adjustable with respect to the housing appliance. Here, a gap area is provided that at least in certain areas is formed by a radial gap—with respect to a longitudinal axis of the platform 4—between the platform and the housing appliance in the area of the surface of the annular channel. A sealing appliance is provided in the area of the gap.

Abstract: A turbine shroud adapted for use in a gas turbine engine includes a plurality of metallic carrier segments and a plurality of blade track segments mounted to corresponding metallic carrier segments. Cooling air is directed onto the blade track segments to cool the blade track segments when exposed to high temperatures in a gas turbine engine.

Abstract: A belly band seal for use in a multi-stage turbomachine having plural rotor disks includes a seal strip positionable in a space between a pair of arms defined by opposing portions of adjoining rotors. The seal strip includes opposite edges for locating in respective slots in end faces of said pair of arms. The belly band seal further includes an anti-rotation structure disposed on a radially inner surface of the seal strip. The anti-rotation structure is configured as a cantilever having a pivoted end fixed to the radially inner surface and a free end comprising a radially inwardly extending engagement member for removably positioning in a radial recess in one of the arms. The cantilever is configured so as to urge the engagement member toward the radial recess by spring action. The radial recess is configured to constrain a tangential movement of the engagement member upon being positioned therein.

Abstract: A sealing structure for a gas turbine engine includes a rotor that has a rim with slots and a cooling passage. The rotor is rotatable about an axis. First and second blades are arranged in the slots and respectively including first and second shelves facing one another within a pocket that is in fluid communication with the cooling passage. The first and second shelves form an opening. A reversible seal is arranged within the pocket and has a body that is configured for operative association with the first and second blades in any of four orientations to seal the opening in a first condition. The seal includes first and second protrusions respectively extending from first and second faces opposing one another. The first protrusions supported on the rim in a first condition.

Abstract: An assembly is provided for rotational equipment. The assembly includes a circumferentially segmented stator and a rotor radially within the stator. The assembly also includes a seal assembly configured for substantially sealing a gap radially between the stator and the rotor. The seal assembly includes a carrier and a non-contact seal seated with the carrier. The carrier includes a plurality of discrete carrier segments circumferentially arranged around the non-contact seal.

Abstract: A sealing system for sealing a sealing gap between an outer housing and a rotor shaft of a rotor of a steam turbine, having a blocking medium wall for producing a blocking medium area between the rotor shaft and the outer housing in the region in front of and/or in the sealing gap, wherein the blocking medium wall is secured to the outer housing. The sealing system also has a blocking medium opening in the blocking medium wall in order to feed a blocking medium from the outside into the blocking medium area. The sealing system also has a shaft seal for sealing the blocking medium area from a second area, which has a second pressure that is lower than the first pressure, and a sliding ring seal for sealing the blocking medium area from a third area, which has a third pressure that is lower than the second pressure.