WO2023276387A1 - エロージョン推定方法 - Google Patents

エロージョン推定方法 Download PDF

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Publication number
WO2023276387A1
WO2023276387A1 PCT/JP2022/016218 JP2022016218W WO2023276387A1 WO 2023276387 A1 WO2023276387 A1 WO 2023276387A1 JP 2022016218 W JP2022016218 W JP 2022016218W WO 2023276387 A1 WO2023276387 A1 WO 2023276387A1
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WO
WIPO (PCT)
Prior art keywords
erosion
steam
pressure
substance
detected
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.)
Ceased
Application number
PCT/JP2022/016218
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English (en)
French (fr)
Japanese (ja)
Inventor
茂樹 妹尾
創一朗 田畑
徹哉 澤津橋
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.)
Mitsubishi Heavy Industries Ltd
Mitsubishi Power Ltd
Original Assignee
Mitsubishi Heavy Industries Ltd
Mitsubishi Power Ltd
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 Mitsubishi Heavy Industries Ltd, Mitsubishi Power Ltd filed Critical Mitsubishi Heavy Industries Ltd
Priority to JP2023531453A priority Critical patent/JP7650974B2/ja
Priority to DE112022001873.9T priority patent/DE112022001873T5/de
Priority to CN202280036969.7A priority patent/CN117355664A/zh
Priority to US18/564,892 priority patent/US20240287914A1/en
Priority to KR1020237039351A priority patent/KR102930954B1/ko
Publication of WO2023276387A1 publication Critical patent/WO2023276387A1/ja
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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Classifications

    • 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
    • F01D25/00—Component parts, details, or accessories, not provided for in, or of interest apart from, other groups
    • F01D25/007—Preventing corrosion
    • 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
    • F01D21/00—Shutting-down of machines or engines, e.g. in emergency; Regulating, controlling, or safety means not otherwise provided for
    • F01D21/003—Arrangements for testing or measuring
    • 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
    • F01D5/00—Blades; Blade-carrying members; Heating, heat-insulating, cooling or antivibration means on the blades or the members
    • F01D5/12—Blades
    • F01D5/28—Selecting particular materials; Particular measures relating thereto; Measures against erosion or corrosion
    • F01D5/282—Selecting composite materials, e.g. blades with reinforcing filaments
    • 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
    • F01D5/00—Blades; Blade-carrying members; Heating, heat-insulating, cooling or antivibration means on the blades or the members
    • F01D5/12—Blades
    • F01D5/28—Selecting particular materials; Particular measures relating thereto; Measures against erosion or corrosion
    • F01D5/286—Particular treatment of blades, e.g. to increase durability or resistance against corrosion or erosion
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K13/00—General layout or general methods of operation of complete plants
    • F01K13/003—Arrangements for measuring or testing
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B37/00—Component parts or details of steam boilers
    • F22B37/02—Component parts or details of steam boilers applicable to more than one kind or type of steam boiler
    • F22B37/38—Determining or indicating operating conditions in steam boilers, e.g. monitoring direction or rate of water flow through water tubes
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N17/00—Investigating resistance of materials to the weather, to corrosion, or to light
    • G01N17/006—Investigating resistance of materials to the weather, to corrosion, or to light of metals
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N17/00—Investigating resistance of materials to the weather, to corrosion, or to light
    • G01N17/02—Electrochemical measuring systems for weathering, corrosion or corrosion-protection measurement
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
    • G01N33/18—Water
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
    • G01N33/20—Metals
    • G01N33/204—Structure thereof, e.g. crystal structure
    • G01N33/2045—Defects
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2220/00—Application
    • F05D2220/30—Application in turbines
    • F05D2220/31—Application in turbines in steam turbines
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2220/00—Application
    • F05D2220/70—Application in combination with
    • F05D2220/72—Application in combination with a steam turbine
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05D—INDEXING SCHEME FOR ASPECTS RELATING TO NON-POSITIVE-DISPLACEMENT MACHINES OR ENGINES, GAS-TURBINES OR JET-PROPULSION PLANTS
    • F05D2260/00—Function
    • F05D2260/80—Diagnostics
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E30/00—Energy generation of nuclear origin
    • Y02E30/30—Nuclear fission reactors

Definitions

  • Patent Document 1 a method of inspecting the water quality of feed water has also been proposed in order to detect corrosion in each part of a steam turbine system.
  • the present disclosure has been made to solve the above problems, and aims to provide an erosion estimation method capable of estimating the progress of erosion simply and at low cost.
  • an erosion estimation method for estimating the progress of erosion of a final stage rotor blade of a steam turbine, wherein sampling feedwater containing a detection target substance from a water supply line connected to the steam turbine; measuring the concentration of the detection target substance in the sampled feedwater; and estimating the progress of erosion.
  • FIG. 1 is a system diagram showing the configuration of a steam turbine system according to an embodiment of the present disclosure
  • FIG. 1 is a schematic diagram showing the configuration of a steam turbine according to an embodiment of the present disclosure
  • FIG. 2 is a schematic diagram showing the configuration of a final stage rotor blade according to an embodiment of the present disclosure
  • 4 is a flow chart illustrating the steps of an erosion estimation method according to an embodiment of the present disclosure
  • 4 is a graph showing an example of the degree of progress of erosion in the final stage rotor blade.
  • FIG. 4 is a system diagram showing a modification of the steam turbine system according to the embodiment of the present disclosure
  • FIG. 1 the steam turbine system 100, the final stage rotor blade 90, and the erosion estimation method according to the embodiment of the present disclosure will be described with reference to FIGS. 1 to 4.
  • FIG. 1 the steam turbine system 100, the final stage rotor blade 90, and the erosion estimation method according to the embodiment of the present disclosure will be described with reference to FIGS. 1 to 4.
  • FIG. 1 the steam turbine system 100, the final stage rotor blade 90, and the erosion estimation method according to the embodiment of the present disclosure will be described with reference to FIGS. 1 to 4.
  • the steam turbine system 100 includes a steam turbine 1, a condenser 2, a condensate pump 3, a low pressure economizer 41, an intermediate pressure economizer 43, and a high pressure economizer 42.
  • a feedwater pump 5 a high-pressure evaporator 61, a medium-pressure evaporator 62, a low-pressure evaporator 63, a high-pressure drum 71, a medium-pressure drum 72, a low-pressure drum 73, a high-pressure superheater 81, and a medium-pressure A superheater 82, a low pressure superheater 83, a reheater 9, a sampling line 10, a feed water line 30, a high pressure steam line 51, an intermediate pressure steam line 52, a low pressure steam line 53, and a extraction line 54. , and a reheat steam line 55 .
  • the steam turbine 1 has a rotating shaft 11 , a casing 12 , a rotor blade row 16 and a stator blade row 18 .
  • the rotating shaft 11 extends along the axis O and is rotatable around the axis O.
  • a pair of journal bearings 14 and one thrust bearing 15 are provided at the shaft ends of the rotating shaft 11 .
  • the journal bearing 14 supports radial loads on the rotating shaft 11 .
  • the thrust bearing 15 supports a load in the direction of the axis O with respect to the rotating shaft 11 .
  • a plurality of rotor blade rows 16 arranged at intervals in the direction of the axis O are provided on the outer peripheral surface of the rotating shaft 11 .
  • Each rotor blade row 16 has a plurality of rotor blades 17 arranged at intervals in the circumferential direction with respect to the axis O.
  • the moving blade 17 included in the moving blade row 16 positioned on the most one side in the direction of the axis O among the plurality of moving blade rows 16 is the final stage moving blade 90 .
  • the casing 12 covers the rotating shaft 11 and the rotor blade row 16 from the outer peripheral side.
  • the casing 12 has a tubular shape centered on the axis O.
  • a steam supply port 12a for introducing steam from the outside is formed on the other side of the casing 12 in the direction of the axis O.
  • a steam discharge port 12b for guiding steam to the outside is formed on one side of the casing 12 in the direction of the axis O.
  • a steam passage is provided between the steam supply port 12a and the steam discharge port 12b.
  • the upstream side the side where the steam supply port 12a is located when viewed from the steam discharge port 12b
  • the opposite side is called the downstream side.
  • a plurality of rows of stationary blades 18 arranged at intervals in the direction of the axis O are provided on the inner peripheral surface of the casing 12 .
  • Each stator blade row 18 has a plurality of stator blades 19 arranged at intervals in the circumferential direction with respect to the axis O.
  • the stator blade rows 18 and the rotor blade rows 16 are alternately arranged in the axis O direction. That is, one rotor blade row 16 is arranged downstream of one stator blade row 18 .
  • the final stage rotor blade 90 has a blade body 91 and an erosion shield 92 .
  • the blade main body 91 extends radially outward from the outer peripheral surface of the rotating shaft 11 described above. When viewed from the radial direction, the cross-sectional shape of the blade main body 91 forms an airfoil shape with a leading edge on the upstream side.
  • An erosion shield 92 is provided on the leading edge side of the tip of the blade main body 91 (that is, the portion including the radially outer end). The erosion shield 92 is provided to prevent erosion from occurring on the surface of the final stage moving blade 90 due to droplets scattered from the row of stator blades 18 on the upstream side.
  • the erosion shield 92 is integrally formed of stellite.
  • Stellite is a metallic material containing cobalt as a main component. Although the details will be described later, in this embodiment, the cobalt element contained in the stellite is called a substance to be detected.
  • a water supply line 30 is connected to the downstream side of the steam turbine 1 (that is, the steam discharge port 12b).
  • a condenser 2 , a condensate pump 3 , a sampling line 10 , a low-pressure economizer 41 , and a feedwater pump 5 are provided on the feedwater line 30 in this order from the steam turbine 1 side.
  • the condenser 2 is a device for cooling the low-pressure steam discharged from the steam turbine 1 and returning it to liquid water.
  • the condensate pump 3 pumps this liquid water downstream on the water supply line.
  • the sampling line 10 is a pipe for taking out part of the water supply flowing through the water supply line 30 to the outside.
  • a low pressure economizer 41 is provided for preheating the feed water.
  • the water supply pump 5 further pumps water in the water supply line 30 .
  • the downstream end of the water supply line 30 is connected to the high pressure economizer 42 .
  • a first branch line 31 is connected between the low-pressure economizer 41 and the water supply pump 5 in the water supply line 30 .
  • a downstream end of the first branch line 31 is connected to a low-pressure evaporator 63, which will be described later.
  • a second branch line 32 is connected to the downstream side of the water supply pump 5 in the water supply line 30 .
  • the downstream end of the second branch line 32 is connected to the medium pressure economizer 43 .
  • the medium-pressure economizer 43 and the high-pressure economizer 42 are devices for preheating feed water.
  • Feed water preheated by the low-pressure economizer 41 is sent to the low-pressure evaporator 63 .
  • the low pressure evaporator 63 further heats the feed water to produce low pressure steam.
  • the feed water preheated by the medium pressure economizer 43 is sent to the medium pressure evaporator 62 .
  • Medium pressure evaporator 62 further heats the feed water to produce medium pressure steam.
  • the feed water preheated by the high pressure economizer 42 is sent to the high pressure evaporator 61 .
  • the high pressure evaporator 61 further heats the feed water to produce high pressure steam.
  • the high-pressure drum 71 is provided for gas-liquid separation of the high-pressure steam generated by the high-pressure evaporator 61 .
  • a gas-phase component of the gas-liquid separation is sent to the high-pressure superheater 81 through the high-pressure steam line 51 .
  • the high-pressure superheater 81 superheats high-pressure steam to generate high-pressure superheated steam.
  • the high pressure superheated steam is sent to the steam turbine 1 through the high pressure steam line 51 .
  • the medium-pressure drum 72 is provided for gas-liquid separation of the medium-pressure steam generated by the medium-pressure evaporator 62 .
  • a gas-phase component of the separated gas-liquid is sent to the medium-pressure superheater 82 through the medium-pressure steam line 52 .
  • the intermediate pressure superheater 82 superheats the intermediate pressure steam to generate intermediate pressure superheated steam.
  • the medium-pressure superheated steam is sent to the reheater 9 through the medium-pressure steam line 52 .
  • the reheater 9 further heats the medium-pressure superheated steam.
  • the superheated steam heated by the reheater 9 is sent to the steam turbine 1 through the reheat steam line 55 . Further, part of the steam extracted from the steam turbine 1 flows into the reheater 9 through the extraction line 54 . This extracted steam is also heated by the reheater 9 and then supplied to the steam turbine 1 through the reheat steam line 55 .
  • the low-pressure drum 73 is provided for gas-liquid separation of the low-pressure steam generated by the low-pressure evaporator 63.
  • a gas-phase component of the gas-liquid separation is sent to the low-pressure superheater 83 through the low-pressure steam line 53 .
  • the low-pressure superheater 83 superheats low-pressure steam to generate low-pressure superheated steam.
  • the low pressure superheated steam is sent to the steam turbine 1 through the low pressure steam line 53 .
  • the method for estimating erosion comprises step S1 of sampling water, step S2 of measuring the concentration of a substance to be detected in the water, and estimating the progress of erosion from the concentration.
  • step S1 part of the water supply is collected through the collection line 10 described above.
  • part of the erosion shield 92 described above is eroded, and a part of the component is contained in the water supply. Therefore, in the present embodiment, the cobalt element contained in the stellite that forms the erosion shield 92 is used as the substance to be detected.
  • step S2 the concentration of cobalt element contained in the sampled water is measured.
  • a plasma emission mass spectrometer is preferably used for concentration measurement.
  • the progress of erosion is estimated based on the cobalt element concentration measured in step S2.
  • erosion is known to follow a time change as shown in the graph of FIG.
  • the horizontal axis of the graph in FIG. 5 is not real time, but equivalent time represented by a function with variables of steam wetness, steam turbine output, and steam flow rate.
  • the vertical axis of the graph represents the progress of erosion. As shown by the curve in the figure, almost no erosion or very little erosion occurs until a certain period of time (initial t1) has elapsed from the start of operation. On the other hand, in a period (transitional period t2) after the initial period t1, erosion progresses rapidly.
  • step S3 the progress of erosion is estimated by comparing with the graph of FIG. 5 based on the amount of time change of the cobalt element. In other words, from the amount of time change of the cobalt element, it is estimated which period in the graph of FIG. 5 corresponds to the current progress of erosion.
  • step S4 it is determined whether or not the progress of erosion is greater than or equal to a threshold.
  • step S4: Yes the last-stage moving blade 90 is replaced or repaired in subsequent step S5.
  • step S4: No steps S1 to S4 are repeated again. All steps of the erosion estimation method according to the present embodiment are completed as described above.
  • the progress of erosion of the last-stage rotor blade 90 can be detected by simply measuring the concentration of the substance to be detected in the feed water without opening the casing 12 of the steam turbine 1. can be estimated.
  • inspection work that involves opening the casing 12 incurs a cost for the work itself, and a large cost for the user because the vehicle cannot be operated during the inspection period.
  • the erosion shield 92 where erosion is most likely to concentrate contains the substance to be detected that is not used in other parts of the steam turbine.
  • the progress of erosion can be estimated with high accuracy based on the concentration of the substance to be detected.
  • the cobalt element is used as the substance to be detected. Cobalt is not used in other parts, and since it exhibits properties similar to those of iron (Fe), it is easy to divert the existing monitoring equipment that was installed for the purpose of detecting iron to estimating erosion. becomes possible.
  • Fe iron
  • the degree of progress of erosion can be estimated by sampling the relatively low-temperature water flowing between the condensate pump 3 and the economizer (low-pressure economizer 41).
  • the burden on the operator can be reduced.
  • the cobalt element contained in the stellite that forms the erosion shield is used as the substance to be detected.
  • the substance to be detected instead of the cobalt element, it is also possible to use a radioactive element impregnated in the final stage rotor blade 90 in advance.
  • a radioactive element is used as the substance to be detected. Radioactive elements are not used in other parts of the steam turbine. Therefore, by using a radioactive element as a substance to be detected, the progress of erosion can be estimated clearly and with high accuracy.
  • a condenser 2 In the thermal power generation system 200, a condenser 2, a condensate pump 3, a sampling line 10, a demineralizer 4b, a condensate booster pump 3b, a plurality of A low-pressure heater 5b, a deaerator 6b, a feedwater pump 7b, a plurality of high-pressure heaters 8b, an economizer 9b, a furnace 10b, and a superheater 11b are provided.
  • the superheated steam generated by the superheater 11b is sent to the steam turbine 1 through the high pressure steam line 51b. Also, part of the steam in the steam turbine 1 is sent to the reheater 13b through the extraction line 52b.
  • the steam heated by the reheater 13b is sent to the steam turbine 1 through the reheat steam line 53b.
  • the sampling line 10 may be provided anywhere within the section from the condenser 2 to the low-pressure heater 5b in the water supply line 30b.
  • An erosion estimation method is an erosion estimation method for estimating the degree of progress of erosion of a final stage rotor blade 90 of a steam turbine 1. a step S1 of sampling feedwater containing a detection target substance from the water supply lines 30, 30b connected to the steam turbine 1; and a step S2 of measuring the concentration of the detection target substance in the sampled feedwater. , and a step S3 of estimating the progress of erosion based on said density.
  • the final stage rotor blade 90 is provided on the blade main body 91 and the leading edge side of the tip portion of the blade main body 91, and is formed of a material containing the detection target substance. and an erosion shield 92 .
  • the detection target substance is contained in the erosion shield 92 where erosion is most likely to concentrate. As a result, progress of erosion can be detected with higher accuracy.
  • the final stage rotor blade 90 may have a blade main body 91 and the detection target substance embedded in the blade main body 91 .
  • the substance to be detected may be cobalt element.
  • the cobalt element is used as the substance to be detected. Since the cobalt element exhibits properties similar to those of iron (Fe), it is possible to easily divert the existing monitoring equipment provided for the purpose of detecting iron content to the estimation of erosion.
  • the substance to be detected may be a radioactive element impregnated in the last stage rotor blade 90 in advance.
  • radioactive elements are used as substances to be detected. Radioactive elements are not used in other parts of steam turbine 1 . Therefore, by using a radioactive element as a substance to be detected, the progress of erosion can be estimated clearly and with high accuracy.
  • the condenser 2 that cools the steam discharged from the steam turbine 1 and returns it to water, and the condenser provided downstream of the condenser 2 A pump 3, an economizer (low-pressure economizer 41) provided downstream of the condensate pump 3 for preheating the water, and heating the water preheated by the economizer to generate steam.
  • the condenser 2 that cools the steam discharged from the steam turbine 1 and returns it to water
  • the condenser provided downstream of the condenser 2 A pump 3
  • an economizer low-pressure economizer 41
  • the feed water may be collected from between the condensate pump 3 and the economizer.
  • the progress of erosion can be estimated by sampling the relatively low-temperature water flowing between the condensate pump 3 and the low-pressure economizer 41 .
  • the burden on the operator can be reduced.

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  • Crystallography & Structural Chemistry (AREA)
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  • Combustion & Propulsion (AREA)
  • Control Of Turbines (AREA)
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PCT/JP2022/016218 2021-06-30 2022-03-30 エロージョン推定方法 Ceased WO2023276387A1 (ja)

Priority Applications (5)

Application Number Priority Date Filing Date Title
JP2023531453A JP7650974B2 (ja) 2021-06-30 2022-03-30 エロージョン推定方法
DE112022001873.9T DE112022001873T5 (de) 2021-06-30 2022-03-30 Erosionsschätzverfahren
CN202280036969.7A CN117355664A (zh) 2021-06-30 2022-03-30 侵蚀估计方法
US18/564,892 US20240287914A1 (en) 2021-06-30 2022-03-30 Erosion estimation method
KR1020237039351A KR102930954B1 (ko) 2021-06-30 2022-03-30 이로전 추정 방법

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JP2021109140 2021-06-30
JP2021-109140 2021-06-30

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JP (1) JP7650974B2 (https=)
KR (1) KR102930954B1 (https=)
CN (1) CN117355664A (https=)
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Citations (4)

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Publication number Priority date Publication date Assignee Title
JPS57131034A (en) * 1981-02-06 1982-08-13 Toshiba Corp Detection of erosion damage to turbine blade
JP2001065303A (ja) * 1999-08-26 2001-03-13 Hitachi Ltd 蒸気タービン翼とその製法及び蒸気タービン発電プラント並びに低圧蒸気タービン
US20120285226A1 (en) * 2011-05-09 2012-11-15 Kurt Neal Laurer Wear-Indicating System For Use With Turbine Engines and Methods Of Inspecting Same
JP2015140762A (ja) * 2014-01-30 2015-08-03 株式会社Ihi エロージョン環境推定方法及びエロージョン寿命推定方法

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JPS6026677A (ja) * 1983-07-25 1985-02-09 Hitachi Ltd 腐食・防食監視制御システム
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