US20080118350A1 - Turbine seal guards - Google Patents

Turbine seal guards Download PDF

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Publication number
US20080118350A1
US20080118350A1 US11/600,539 US60053906A US2008118350A1 US 20080118350 A1 US20080118350 A1 US 20080118350A1 US 60053906 A US60053906 A US 60053906A US 2008118350 A1 US2008118350 A1 US 2008118350A1
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US
United States
Prior art keywords
axial fin
upstream
downstream
fin
opening
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Abandoned
Application number
US11/600,539
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English (en)
Inventor
Sean Feeny
Michael Montgomery
Mark Bowen
Stephen Swan
David Caruso
Wei-Min Ren
Michael Hamlin
Jeffrey Simkins
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
General Electric Co
Original Assignee
General Electric Co
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by General Electric Co filed Critical General Electric Co
Priority to US11/600,539 priority Critical patent/US20080118350A1/en
Assigned to GENERAL ELECTRIC COMPANY reassignment GENERAL ELECTRIC COMPANY ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: CARUSO, DAVIS, MONTGOMERY, MICHAEL, REN, WEI-MIN, FEENY, SEAN, HAMILIN, MICHAEL, SIMKINS, JEFFREY, SWAN, STEPHEN
Priority to FR0758675A priority patent/FR2908815A1/fr
Priority to RU2007142281/06A priority patent/RU2007142281A/ru
Priority to DE102007054926A priority patent/DE102007054926A1/de
Priority to JP2007296269A priority patent/JP2008128240A/ja
Publication of US20080118350A1 publication Critical patent/US20080118350A1/en
Abandoned legal-status Critical Current

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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01D—NON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
    • F01D11/00—Preventing or minimising internal leakage of working-fluid, e.g. between stages
    • F01D11/08—Preventing or minimising internal leakage of working-fluid, e.g. between stages for sealing space between rotor blade tips and stator

Definitions

  • This present application relates generally to systems for protecting turbine components from solid particle erosion and deposits. More specifically, but not by way of limitation, the present application relates to systems for providing a seal guard to deflect solid particles away from turbine seal components.
  • the turbine components that reside in the main steam flowpath generally are protected through specialized coatings or mechanical hardening.
  • the components related to the annular seals typically are made from softer materials and are not treated with specialized coatings or mechanically hardened since the softer material is desirable in the event that rubbing between the stationary and rotating components occurs.
  • Solid particles that contact the annular seal components thus, often cause erosion and degradation to occur. Such erosion includes the flattening or rounding of the overlapping teeth that form the annular seals, which over time leads to performance and potentially larger reliability issues if the structural integrity of the any of teeth is compromised.
  • Solid particles also may become lodged within the annular seal, which, given the rotational velocity of the rotating parts and the tolerances within the seal between the stationary and rotating parts, may cause significant damage to the seal. In such a situation, the solid particle may cause the rotating and stationary surfaces to rub, which may compromise the structural integrity of the annular seal and/or damage the overlapping teeth that form the seal, leading to increased leakage and reduced turbine efficiency.
  • the present application thus may describe a system for preventing solid particle erosion in a turbine.
  • the turbine may include turbine blades that include a blade cover and an opening defined by a trailing edge of a nozzle and a leading edge of the blade cover.
  • the system may include at least one of an upstream axial fin positioned at the trailing edge of the nozzle and a downstream axial fin positioned at the leading edge of the blade cover.
  • the trailing edge of the nozzle may include an outer sidewall.
  • the upstream axial fin may include a fin that protrudes from the outer sidewall in a downstream direction.
  • the upstream axial fin may extend in a substantially continuous circumferential manner.
  • the upstream axial fin may include a fin that extends in an axial manner across at least part of the opening.
  • the downstream axial fin may include a fin that protrudes from the blade cover in an upstream direction.
  • the downstream axial fin further may include a fin that extends in an axial manner across at least part of the opening.
  • the downstream axial fin may extend in a substantially continuous circumferential manner.
  • the system may include both an upstream axial fin and a downstream axial fin.
  • the upstream axial fin and the downstream axial fin may include approximately the same radial position and substantially span the axial distance of the opening.
  • the downstream axial fin may be positioned slightly more outward radially than the upstream axial fin.
  • the downstream axial fin and the upstream axial fin may overlap axially.
  • the upstream axial fin may be an integral part of the outer sidewall. In some embodiments, the upstream axial fin may be attached to the outer sidewall by welding or peening.
  • the system may further include a downstream groove positioned in the leading edge of the blade cover.
  • the upstream axial fin may span the opening and terminate within the downstream groove.
  • the system further may include an upstream groove positioned in the trailing edge of the nozzle.
  • the downstream axial fin may span the opening and terminate within the downstream groove.
  • the application may further describe a seal guard in a turbine where the turbine include a plurality of circumferentially spaced nozzles, a plurality of circumferentially spaced turbine blades that each include a blade cover, and an opening defined by a trailing edge of the nozzles and a leading edge of the blade covers.
  • the seal guard may include an upstream axial fin positioned at the trailing edge of the nozzles that extends in a downstream direction across at least part of the opening or a downstream axial fin positioned at a leading edge of a blade cover that extends in an upstream direction across at least part of the opening.
  • the system may include both the upstream axial fin and the downstream axial fin, and the upstream axial fin and the downstream axial fin may include approximately the same radial position and substantially span the axial distance of the opening.
  • the downstream axial fin may be positioned slightly more outward radially than the upstream axial fin and the upstream axial fin and the downstream axial fin may overlap axially.
  • the system may include a downstream groove positioned in the leading edge of the blade cover.
  • the upstream axial fin may span the opening and terminate within the downstream groove.
  • the system may include an upstream groove positioned the trailing edge of the nozzle.
  • the downstream axial fin may span the opening and terminate within the upstream groove.
  • FIG. 1 is a schematic line drawing illustrating a cross-sectional view of an exemplary environment, i.e., a conventional turbine stage, in which an embodiment of the present application may operate.
  • FIG. 2 is a schematic line drawing illustrating a cross-sectional view of a turbine stage with a seal guard in accordance with an exemplary embodiment of the present application.
  • FIG. 3 is a schematic line drawing illustrating a cross-sectional view of a turbine stage with a seal guard in accordance with a further alternative embodiment of the present application.
  • FIG. 4 is a schematic line drawing illustrating a cross-sectional view of a turbine stage with a seal guard in accordance with another alternative embodiment of the present application.
  • FIG. 5 is a schematic line drawing illustrating a cross-sectional view of a turbine stage with a seal guard in accordance with another alternative embodiment of the present application.
  • FIG. 6 is a schematic line drawing illustrating a cross-sectional view of a turbine stage with a seal guard in accordance with another alternative embodiment of the present application.
  • FIG. 1 illustrates a cross-sectional view of an exemplary environment in which an embodiment of the present application may operate, a turbine stage 10 .
  • the turbine stage 10 may be a stage within a steam or gas turbine or other type of turbo machinery.
  • the turbine stage 10 may include a plurality of circumferentially spaced nozzles 12 .
  • the nozzle 12 may be a stationary component that directs the flow of a working fluid onto a plurality of circumferentially spaced turbine blades 14 .
  • the turbine blade 14 may include an airfoil 16 , which extends from a base 18 .
  • the base 18 of the turbine blade 14 may connect to a rotor (not shown) such that, in operation, the configuration of the airfoil 16 and the flow of working fluid causes the turbine blades 14 to rotate about the rotor, thus converting the energy of the flow of working fluid into mechanical energy.
  • each of the turbine blades 14 may be connected to a blade cover 20 .
  • the blade cover 20 may be integral to the turbine blade 14 or may be attached thereto pursuant to conventional methods.
  • the blade cover 20 may be a surface or structure at the outward radial end of the airfoil 16 that runs substantially perpendicular to the surface of the airfoil 16 .
  • the blade covers may prevent working fluid from leaking over the end of the airfoil 16 , which is advantageous because working fluid that leaks over the end of the airfoil 16 does less work thereby decreasing the efficiency of the turbine.
  • the blade cover 20 also may be known as a tip shroud or a bucket cover.
  • Each of the blade covers 20 may extend in a circumferential manner toward the blade covers 20 of the neighboring turbine blades 14 . Each of the blade covers 20 may abut the two neighboring blade covers 20 . In this manner, the blade covers 20 may create an essentially continuous (though segmented) circumferential ring within the turbine. In another type of construction, the blade covers may span multiple turbine blades. These larger blade covers (not pictured) may then abut each other to form the circumferential ring within the turbine.
  • cover teeth 24 At an outward radial surface 22 of the blade cover 20 , one or more cover teeth 24 may be positioned.
  • the cover teeth 24 which also may be known as vernier teeth, may include tapering or step protrusions that point in the outward radial direction from the outward radial surface 22 .
  • the turbine stage 10 further may include a spill strip 26 .
  • the spill strip 26 may be a stationary component that includes a series of abutting arcing segments that, upon assembly, create an essentially continuous circumferential ring in the turbine.
  • one or more spill strip teeth 30 may be positioned at an inward radial surface 28 of the spill strip 26 .
  • the spill strip teeth 30 which may be vernier style, hi-lo style, interlocking style, or any other commonly used style of seal teeth, may include tapering or step protrusions that point in the inward radial direction from the inward radial surface 28 .
  • the spill strip teeth 30 and the cover teeth 24 may be positioned such that they form a seal 32 between the blade cover 20 and the spill strip 26 , which also may be referred to as an annular, hi-lo, interlocking, or vernier seal. More specifically, the spill strip teeth 30 and the cover teeth 24 may form overlapping or interlocking teeth along the axial length of the blade cover 20 /spill strip 26 such that a seal is created that limits the axial movement of working fluid in this area.
  • the spill strip 26 may connect or be integral to a turbine casing 34 , which may form an outer casing that encloses the turbine. In addition, in other assemblies, the spill strip 26 may be mounted in the casing, a diaphragm blade/ring carrier, or the downstream diaphragm/blade ring.
  • Working fluid such as air in a gas turbine or steam in a steam turbine, may flow through the turbine stage 10 .
  • the working fluid flows through a main flowpath of the turbine (i.e., across the nozzles 12 and then across the airfoils 16 ).
  • the flow of the main flowpath is depicted in FIG. 1 by arrows 36 .
  • Working fluid may deviate from the main flowpath and flow into opening 38 .
  • the direction of such flow is depicted in FIG. 1 by arrow 40 .
  • Working fluid that flows into opening 38 then may contact the components associated with the seal 32 , including the spill strip teeth 30 and the cover teeth 24 .
  • Certain impurities which as used herein may include solid particles or other impurities, may be contained in the working fluid. These solid particles may flow within the main flowpath (as depicted by the arrows 36 ) and contact turbine components within the main flowpath, such as the nozzles 12 and the airfoils 16 . As described, components in the main flowpath generally are protected by specialized coatings or mechanical hardening such that contact with solid particles causes little or no erosion or degradation to the components. The solid particles also may flow into the opening 38 . The frequency of this occurrence is increased by the relatively large axial distance of the opening 38 (i.e., the axial distance defined by the outer trailing edge of the nozzle 12 and the inner leading edge of the blade cover 20 ) in conventional turbine design.
  • a first method includes using a nozzle 12 with an integrally formed outer sidewall 46 and inner sidewall 47 .
  • a second method of nozzle assembly uses band/ring construction. In this type of assembly, the nozzles are first welded between inner and outer bands, which extend about 180°. Those arcuate bands with welded airfoils are then assembled and welded between inner and outer carrier rings of the stator of the turbine. Under this second method of nozzle assembly, the leading edge of the opening 38 would be defined by the outer band, which is not depicted in the figures.
  • a third method of assembly uses one or more large pieces of material out of which the nozzles are machined. This method is sometimes referred to as “bling” construction.
  • leading edge of the opening 38 will be referred to generally herein as the trailing edge of the nozzle 12 and, more specifically, as the trailing edge of the outer sidewall 46 .
  • leading edge of the opening 38 when other nozzle assembly configurations are used, may be defined by other components, such as the outer band component discussed above as well as the outer ring 48 , the nozzle 12 and/or other stationary components.
  • Reference herein to the trailing edge of the nozzle 12 or outer sidewall 46 thus, is meant to include those other components that may define the leading edge of the opening 38 in the other types of nozzle assembly configurations.
  • the solid particles may contact components that typically are made from softer materials and are not treated with specialized coatings or mechanically hardened, such as the cover teeth 24 or the spill strip teeth 30 .
  • Solid particles that contact these seal 32 components often cause erosion to occur, which, over time, may significantly damage the cover teeth 24 and/or the spill strip teeth 30 such that the performance of the seal 32 is negatively affected and leakage increases. That is, if the teeth become worn and the overlap between the cover teeth 24 or the spill strip teeth 30 is lessened or destroyed, a greater amount of working fluid will be able to leak through the seal 32 . Of course, energy is not extracted from working fluid that travels through the seal, thus decreasing the efficiency of the turbine.
  • the seal guard 50 may include an upstream axial fin 52 that protrudes in a downstream axial direction from the outer sidewall 46 of the nozzle 12 .
  • more than one axial fin 52 may be provided. More specifically, the upstream axial fin 52 may jut in an axial manner from the outer sidewall 46 across the opening 38 .
  • the upstream axial fin 52 may originate from the outer ring 48 (i.e., the upstream axial fin 52 may jut in an axial manner from the outer ring 48 across the opening 38 ). At its termination, the trailing edge of the upstream axial fin 52 may be located in close proximity to the leading edge of the blade cover 20 . The upstream axial fin 52 may span part or all of the axial distance of the opening 38 . In some embodiments, as illustrated in FIG. 2 , the end of the upstream axial fin 52 may taper to a point 54 .
  • the upstream axial fin 52 may run in a substantially continuous circumferential manner within the turbine. That is, in some embodiments of nozzle construction, the outer sidewalls 46 of neighboring nozzles 12 may abut to form a substantially continuous circumferential ring.
  • the upstream axial fin 52 may be configured on the outer sidewall 46 (i.e., such that it covers the entire circumferential length of the outer sidewall 46 ) such that the upstream axial fin 52 runs in a continuous manner (though segmented) around the circumference of the turbine. In other embodiments of nozzle construction, the upstream axial fin 52 may run in a continuous manner around the circumference of the turbine due to other aspects of the configuration of the outer sidewall 46 or outer ring 48 construction.
  • the seal guard 50 may include a downstream axial fin 58 that protrudes in an upstream direction from the blade cover 20 .
  • more than one downstream axial fin 58 may be included. More specifically, the downstream axial fin 58 may jut in an axial manner from the blade cover 20 across the opening 38 .
  • the downstream axial fin 58 may span approximately part or all of the axial distance of the opening 38 .
  • the end of the downstream axial fin 58 may taper to a point 60 .
  • the downstream axial fin 58 may run in a substantially continuous circumferential manner. That is, the blade cover 20 of neighboring turbine blades 14 may abut to form a substantially continuous circumferential ring.
  • the downstream axial fin 58 may be configured on the blade cover 20 (i.e., such that it covers the entire circumferential length of the blade cover 20 ) such that the downstream axial fin 58 runs in a continuous manner (though segmented) around the circumference of the turbine.
  • a combination of the upstream axial fin 52 and the downstream axial fin 58 may be used such that they substantially span the axial distance of the opening 38 .
  • the downstream axial fin 58 may be positioned slightly more outward radially than the upstream axial fin 52 . Though not shown, in some embodiments, this positioning may allow the upstream axial fin 52 and the downstream axial fin 58 to overlap axially.
  • the upstream axial fin 52 may be formed using several methods. In some embodiments, the upstream axial fin 52 may be machined per conventional methods as an integral part of the outer sidewall 46 or the outer ring 48 . As stated, in some turbines, the upstream edge of the opening 38 may be defined by an outer band. In such cases, the upstream axial fin 52 may be machined as an integral part of the outer band.
  • the upstream axial fin 52 may be made of an alloy steel (such as 12-chrome, stainless steel, or low alloy steel) and may be, but not necessarily, mechanically hardened through flame hardening or other similar mechanical processes.
  • a coating may be used on the upstream axial fin 52 such as those typically used on components in the flow path rather than a mechanical hardening process. The purpose of this mechanical hardening or providing a protective coating would be to allow the upstream axial fin 52 to better resist erosion from the solid particles.
  • the upstream axial fin 52 also may be welded onto an outer sidewall 46 , or in other cases (not shown), the outer ring 48 .
  • the upstream axial fin 52 may be welded to an outer sidewall 46 that lacks such a component.
  • a long tapering piece 70 may be welded to the trailing edge of the outer sidewall 46 such that the upstream axial fin 52 is formed.
  • a weld 72 located at the upward radial surface of the long tapering piece 70 and a weld 74 located at the lower leading edge of the long tapering piece 70 may be used, though those of ordinary skill in the art will recognize that other weld configurations may be used.
  • the welded upstream axial fin 52 may be made from a different material than the outer sidewall 46 . Stellite, inconel, or other similar alloys or materials, which generally are more resistant to solid particle erosion than the material of the outer sidewall 46 or outer ring 48 , may be used. In other embodiments, the welded upstream axial fin 52 may be made from the same material as the outer sidewall 46 or outer ring 48 .
  • the upstream axial fin 52 may be attached to the outer sidewall 46 , or in other cases (not shown), the outer ring 48 , by mechanically connecting or peening the component into place.
  • a tapering or rectangular piece 80 may be used to form the upstream axial fin 52 .
  • the rectangular piece 80 may include a dovetail or hook 82 at one end, but it may also include other configurations that lend themselves to mechanical connection or peening. During installation, the hook 82 may be inserted into a dovetail or groove 84 in the outer sidewall 46 .
  • the outer sidewall 46 then may be peened at a location adjacent to the groove 86 such that the outer sidewall 46 is deformed and the hook 82 is mechanically locked within the groove 84 .
  • the outer sidewall 46 or outer ring 48 also may include a secondary, smaller groove (not shown) that aids in the mechanical deformation of the peening process.
  • the mechanically connecting or peening of the upstream axial fin 52 into place also would allow the upstream axial fin 52 to be made from a different material than that of the outer sidewall 46 or outer ring 48 .
  • Stellite, inconel, or other similar alloys or materials which generally are more resistant to solid particle erosion than the material of the outer sidewall 46 or outer ring 48 , may be used.
  • the mechanically connected or peened upstream axial fin 52 may be made from the same material as the outer sidewall 46 or outer ring 48 .
  • attaching the upstream axial fin 52 by mechanically connecting or peening may allow for the upstream axial fin 52 to be efficiently retrofitted into existing outer sidewalls 46 or outer rings 48 (or any of the other components that may define the upstream edge of the opening 38 ).
  • the upstream axial fin 52 may be added to a turbine in which significant solid particle erosion has occurred to prevent further erosion from occurring.
  • the upstream axial fin 52 may be applied to an existing flowpath or to a new flowpath.
  • the downstream axial fin 58 may be formed by methods similar to those described above for the upstream axial fin 52 . That is, the downstream axial fin 58 may be an integral part machined as part of the blade cover 20 or may be welded or mechanically connected or peened into place to an existing blade cover 20 . The downstream axial fin 58 may be made from the same materials as described above for the upstream axial fin 52 .
  • the seal guard 50 may provide a shield to deflect solid particle impurities from entering the opening 38 .
  • the seal guard 50 also may alter the flow characteristics around the opening 38 so that solid particle impurities are carried away from the opening 38 .
  • the solid particle impurities, thus deflected or carried away within the main flowpath, would not be able to come in contact with or erode the components of the seal 32 (and other turbine components in this area of the turbine) and the performance of the turbine would not be adversely affected by increased leakage.
  • the upstream axial fin 52 and the downstream axial fin 58 would significantly reduce the axial extent of the opening 38 , which would reduce the number of solid particles entering the opening 38 .
  • the upstream axial fin 52 and its tapering point 54 would replace the existing gradual curvature at the leading edge of the opening 38 that invites solid particles to enter.
  • the upstream axial fin 52 may be used without the downstream axial fin 58 . In such embodiments, the upstream axial fin 52 may be configured such that it spans a significant percentage of the opening 38 . Further, as illustrated in FIG. 5 , the upstream axial fin 52 may be used with a downstream groove 90 .
  • the downstream groove 90 may be a groove or recess within the blade cover 20 . In such embodiments, the upstream axial fin 52 may span the opening 38 and terminated within the downstream groove 90 .
  • the downstream axial fin 58 may be used without the upstream axial fin 52 .
  • the downstream axial fin 58 may be configured such that it spans a significant percentage of the opening 38 .
  • the downstream axial fin 58 may be used with an upstream groove 94 .
  • the upstream groove 94 may be a groove or recess within the outer sidewall 46 or outer ring 48 .
  • the downstream axial fin 58 may span the opening 38 and terminated within the upstream groove 94 .
  • the upstream axial fin 52 may overlap or almost overlap with the downstream axial fin 58 , shown in FIG. 2 .
  • the downstream axial fin 58 may be positioned slightly more outward radially than the upstream axial fin 52 .

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Turbine Rotor Nozzle Sealing (AREA)
US11/600,539 2006-11-16 2006-11-16 Turbine seal guards Abandoned US20080118350A1 (en)

Priority Applications (5)

Application Number Priority Date Filing Date Title
US11/600,539 US20080118350A1 (en) 2006-11-16 2006-11-16 Turbine seal guards
FR0758675A FR2908815A1 (fr) 2006-11-16 2007-10-30 Protections de joint de turbine
RU2007142281/06A RU2007142281A (ru) 2006-11-16 2007-11-15 Ограждения для уплотнения турбины
DE102007054926A DE102007054926A1 (de) 2006-11-16 2007-11-15 Schutzvorrichtung für Turbinendichtungen
JP2007296269A JP2008128240A (ja) 2006-11-16 2007-11-15 タービンシールガード

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
US11/600,539 US20080118350A1 (en) 2006-11-16 2006-11-16 Turbine seal guards

Publications (1)

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US20080118350A1 true US20080118350A1 (en) 2008-05-22

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ID=39339113

Family Applications (1)

Application Number Title Priority Date Filing Date
US11/600,539 Abandoned US20080118350A1 (en) 2006-11-16 2006-11-16 Turbine seal guards

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US (1) US20080118350A1 (ja)
JP (1) JP2008128240A (ja)
DE (1) DE102007054926A1 (ja)
FR (1) FR2908815A1 (ja)
RU (1) RU2007142281A (ja)

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20090010754A1 (en) * 2005-12-12 2009-01-08 Keshava Kumar Bearing-Like Structure to Control Deflections of a Rotating Component
CN102080573A (zh) * 2009-11-26 2011-06-01 阿尔斯托姆科技有限公司 轴流式蒸汽涡轮
US20150132114A1 (en) * 2013-11-08 2015-05-14 Mitsubishi Hitachi Power Systems, Ltd. Axial turbine
US9476315B2 (en) 2012-10-25 2016-10-25 Mitsubishi Hitachi Power Systems, Ltd. Axial flow turbine
US9732627B2 (en) 2012-08-02 2017-08-15 Kabushiki Kaisha Toshiba Sealing structure in steam turbine
US9835040B2 (en) 2013-10-08 2017-12-05 MTU Aero Engines AG Turbomachine
US10316677B2 (en) * 2015-04-09 2019-06-11 Rolls-Royce Deutschland Ltd & Co Kig Shroud arrangement of a row of blades of stator vanes or rotor blades
US11168576B2 (en) * 2019-02-27 2021-11-09 Mitsubishi Power, Ltd. Axial flow turbine

Families Citing this family (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2428649A1 (de) * 2010-09-10 2012-03-14 Siemens Aktiengesellschaft Drallbrecher in einer Leckageströmung einer Strömungsmaschine
JP6192990B2 (ja) * 2013-05-31 2017-09-06 三菱日立パワーシステムズ株式会社 軸流タービン
JP6153650B2 (ja) * 2016-08-03 2017-06-28 三菱日立パワーシステムズ株式会社 蒸気タービンの静止体及びこれを備えた蒸気タービン
JP6924233B2 (ja) * 2019-08-30 2021-08-25 三菱パワー株式会社 回転機械

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US4776765A (en) * 1985-07-29 1988-10-11 General Electric Company Means and method for reducing solid particle erosion in turbines
US5249918A (en) * 1991-12-31 1993-10-05 General Electric Company Apparatus and methods for minimizing or eliminating solid particle erosion in double-flow steam turbines
US6116608A (en) * 1998-11-12 2000-09-12 General Electric Co. Apparatus for guiding solid particles through a brush seal in a turbine
US6679681B2 (en) * 2002-04-10 2004-01-20 General Electric Company Flush tenon cover for steam turbine blades with advanced sealing
US20040253100A1 (en) * 2003-05-13 2004-12-16 Alstom Technology Ltd Axial flow steam turbines

Patent Citations (7)

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Publication number Priority date Publication date Assignee Title
US4776765A (en) * 1985-07-29 1988-10-11 General Electric Company Means and method for reducing solid particle erosion in turbines
US4776765B1 (ja) * 1985-07-29 1992-06-30 Gen Electric
US5249918A (en) * 1991-12-31 1993-10-05 General Electric Company Apparatus and methods for minimizing or eliminating solid particle erosion in double-flow steam turbines
US5295301A (en) * 1991-12-31 1994-03-22 General Electric Company Method for minimizing or eliminating solid particle erosion in double-flow steam turbines
US6116608A (en) * 1998-11-12 2000-09-12 General Electric Co. Apparatus for guiding solid particles through a brush seal in a turbine
US6679681B2 (en) * 2002-04-10 2004-01-20 General Electric Company Flush tenon cover for steam turbine blades with advanced sealing
US20040253100A1 (en) * 2003-05-13 2004-12-16 Alstom Technology Ltd Axial flow steam turbines

Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20090010754A1 (en) * 2005-12-12 2009-01-08 Keshava Kumar Bearing-Like Structure to Control Deflections of a Rotating Component
US8205431B2 (en) * 2005-12-12 2012-06-26 United Technologies Corporation Bearing-like structure to control deflections of a rotating component
CN102080573A (zh) * 2009-11-26 2011-06-01 阿尔斯托姆科技有限公司 轴流式蒸汽涡轮
US9732627B2 (en) 2012-08-02 2017-08-15 Kabushiki Kaisha Toshiba Sealing structure in steam turbine
US9476315B2 (en) 2012-10-25 2016-10-25 Mitsubishi Hitachi Power Systems, Ltd. Axial flow turbine
US9835040B2 (en) 2013-10-08 2017-12-05 MTU Aero Engines AG Turbomachine
US20150132114A1 (en) * 2013-11-08 2015-05-14 Mitsubishi Hitachi Power Systems, Ltd. Axial turbine
US10316677B2 (en) * 2015-04-09 2019-06-11 Rolls-Royce Deutschland Ltd & Co Kig Shroud arrangement of a row of blades of stator vanes or rotor blades
US11168576B2 (en) * 2019-02-27 2021-11-09 Mitsubishi Power, Ltd. Axial flow turbine

Also Published As

Publication number Publication date
RU2007142281A (ru) 2009-05-20
FR2908815A1 (fr) 2008-05-23
DE102007054926A1 (de) 2008-06-05
JP2008128240A (ja) 2008-06-05

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