CN102004460A - Online monitoring method for fouling degree of flow passage of steam turbine - Google Patents
Online monitoring method for fouling degree of flow passage of steam turbine Download PDFInfo
- Publication number
- CN102004460A CN102004460A CN 201010564644 CN201010564644A CN102004460A CN 102004460 A CN102004460 A CN 102004460A CN 201010564644 CN201010564644 CN 201010564644 CN 201010564644 A CN201010564644 A CN 201010564644A CN 102004460 A CN102004460 A CN 102004460A
- Authority
- CN
- China
- Prior art keywords
- pressure
- steam
- flow
- steam turbine
- turbine
- 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.)
- Pending
Links
Images
Landscapes
- Control Of Turbines (AREA)
Abstract
The invention relates to an online monitoring method for fouling degree of a flow passage of a steam turbine, which is characterized by comprising the links of data acquisition, main steam flow calculation, back-heating system parameter correction and diagnosis of the fouling degree of the flow passage, and comprising the following steps of: for each middle group, comparing the front and back pressure ratio of each group obtained by online monitoring with the front and back pressure ratio of each group when the flow passage is in a normal state by using the current back-heating extraction pressure measuring point of each level in the running of the steam turbine through the links so as to judge the fouling state of the flow passage of each middle group of the steam turbine; for the final group, comparing the pressure before the final group obtained by online monitoring with the pressure before the final group of the steam turbine under the condition of the same main steam flow so as to judge the fouling condition of the flow passage area of the final group of the steam turbine and realize the online diagnosis of the fouling degree of the whole flow passage of the steam turbine. The invention has the advantage of scientific method, and can realize automatic online monitoring and accurate judgment, and the like.
Description
Technical field
The present invention relates to heat power equipment condition monitoring and fault diagnosis field, is a kind of accurate on-line monitoring method of Turbine Flow Path fouling degree.
Background technology
Along with the development of China's fired power generating unit to high parameter high capacity direction, especially putting into operation of high-capacity direct current boiler and super (surpassing) critical unit is difficult to the higher steam quality of control.Simultaneously, super (surpassing) critical unit is owing to the raising of vapor pressure, and the solubleness of salt in steam increases, and has further increased the difficulty of boiler desalination.Be dissolved with the steam of salt, enter steam turbine acting back, make the salt that is dissolved in the steam separate out because pressure reduces, be deposited in the Turbine Flow Path, cause the Turbine Flow Path fouling, cause the Turbine Flow Path thermal parameter to change, axial thrust increases.The Turbine Flow Path fouling has had a strong impact on the economy and the security of steam turbine operation.Therefore, the accurate on-line monitoring of Turbine Flow Path fouling is very important with diagnosis.
At present, on-line monitoring for Turbine Flow Path fouling in service does not still have ripe method, open (bulletin) number CN101334358A of Chinese invention patent, after name is called " assay method of all-silicon content in the turbine blade scale sample ingredient " and has just provided the Turbine Flow Path fouling, the assay method of all-silicon content in the blade scale sample ingredient, fouling is not diagnosed to Turbine Flow Path, the analysis of blade scale forming element in the time of only organizing overhaul as level, thereby can not realize diagnosis to Turbine Flow Path fouling in service; Open (bulletin) number CN101334393A of Chinese invention patent, name is called " turbine blade salification, fouling constituent analysis disposal route " and has provided after Turbine Flow Path, when unit is opened the cylinder overhaul, to the disposal route of fouling, Turbine Flow Path fouling in service is not diagnosed.Open (bulletin) number CN201000327Y of China's utility model patent, it is to utilize the difference of online detection fouling thickness growth for the fouling difference variation that name is called " a kind of water fouling on-line measuring device ", realize for the instant objective evaluation of the fouling situation of water system, the measuring point temperature is higher but steam turbine itself draws gas, after the turbine blade fouling, temperature does not have to change substantially, therefore can not be as the diagnosis to Turbine Flow Path fouling in service.
Simultaneously, lot of documents report Turbine Flow Path fouling diagnostic method has been arranged.Document [1] (the other Zorovic work of (Soviet Union) card. the steam turbine equipment operation. hydraulic and electric engineering publishing house, 1988) adopt the method for monitoring steam turbine monitor section pressure to judge whether fouling of Turbine Flow Path, promptly under same main steam flow, monitor by judging whether section pressure surpasses design load 10% and judge flow passage component fouling situation, and the characteristics of this method are directly perceived, convenient.But shortcoming is to monitor that the section pressure-measuring-point is far away more from the level of fouling, and then fouling is more little to monitoring section pressure influence.And, monitor that section pressure also is subjected to the heat regenerative system running status such as the influence of factors such as heater terminal is poor, the regenerative steam pressure loss, well heater radiation loss.Thereby have influence on diagnostic accuracy.Document [2] (Wang Yibing, high turbulent waves. the Theoretical Calculation of turbine blade fouling thickness. steam turbine technology, 1998,40 (5): 286-287) propose a kind of method of calculating Turbine Flow Path fouling thickness, but this method need pre-determine fouling thickness proportion coefficients at different levels.In fact, Turbine Flow Path fouling degree is not only relevant with the pressure and temperature of working steam, and, also relevant with factors such as steam turbine structural parameters, local condition of water quality.Therefore, in the steam turbine actual motion, be difficult to accurately determine fouling thickness proportion coefficients at different levels.Document [3] (high turbulent waves, bronze bell high mountain. a kind of new method of turbine blade fouling inline diagnosis.Dalian University of Technology's journal, 1999,34 (4): 538-541.) set up the relation of Turbine Flow Path fouling and thermodynamic parameters, and be training sample, set up the neural network model of differentiating Turbine Flow Path fouling degree with heating power result of calculation.But it is when determining the concerning of flow passage component fouling and thermodynamic parameters, not only need to pre-determine fouling thickness proportion coefficients at different levels, but also need pre-determine the average thickness of Turbine Flow Path fouling, these data all are difficult to accurately determine in the steam turbine operation process.
Summary of the invention
At the existing defective that exists about Turbine Flow Path fouling on-line monitoring and diagnostic monitoring method and device, the objective of the invention is to based on temperature, pressure and flow measuring point conventional in the steam turbine operation, calculate in conjunction with computer program, provide a kind of and can monitor automatically, the accurate on-line monitoring method of the Turbine Flow Path fouling degree of tracing trouble.
Design of the present invention basis is:
1. theory and practice confirms, under the normal situation of Turbine Flow Path state, when main steam flow changed, except governing stage and final stage, the level group back and the level of middle each grade group were organized a preceding pressure ratio and kept its corresponding design load constant; After the Turbine Flow Path fouling, under same main steam flow condition, the level group back of each grade group and the pressure ratio (hereinafter to be referred as pressure ratio before and after the level group) before the level group will reduce in the middle of the steam turbine.
2. for final stage group, the pressure before the level group is directly proportional with steam flow, and still, the pressure after the final stage group is condenser pressure, and it is not directly proportional with steam flow obviously.Therefore, for final stage group, can not adopt the situation of change of pressure ratio to diagnose the Turbine Flow Path fouled condition.Consider that the final stage of condensing turbine is in critical or supercritical flow state, when final stage group flow passage component state just often, under identical main steam flow condition, the pressure before the final stage group remains unchanged; When final stage group flow passage component fouling, the pressure before the final stage group will be higher than under the condition of identical main steam flow the pressure before the final stage group.
3. in addition, in the middle of the steam turbine after each grade group with the level group before pressure ratio and the pressure before the final stage group, also be subjected to the influence of Steam Turbine Regenerative System running status.For this reason, after centre each grade group that actual measurement should be obtained with the level group before pressure ratio and the pressure before the final stage group, be adapted to heat regenerative system state analog value just often.
The present invention is exactly under above-described three prerequisites, according to the principal character of Turbine Flow Path fouling, has proposed a kind of on-line monitoring method of Turbine Flow Path fouling degree, to realize the online quantitative Diagnosis to Turbine Flow Path fouling degree.
Technical scheme of the present invention is: a kind of on-line monitoring method of Turbine Flow Path fouling degree is characterized in that it may further comprise the steps:
(a) data acquisition link is utilized regenerative steam pressure-measuring-points at different levels in the steam turbine operation, measures in the middle of the steam turbine pressure before pressure before and after at different levels groups, the final stage group, and pressure ratios before and after at different levels groups in the middle of calculating;
(b) main steam flow calculates link, by calculating to the regenerative steam amount of each high-pressure heater and oxygen-eliminating device, and utilize oxygen-eliminating device inlet condensing water flow table meter, and consider reheater, superheater desuperheating water flow and boiler blow-off amount simultaneously, determine the main steam flow of steam turbine;
(c) heat regenerative system parameter correction link, based on steam turbine isentropic expansion process line, the backheat bleed off passage is all got the intersection point between isentropic expansion process and the corresponding regenerative steam pressure, determine the regenerative steam amount that steam turbine waits until that entropy expands, utilize the Fu Liugeer formula to find the solution the front and back pressure ratio of at different levels groups of revised centres, utilize the proportional principle of pressure before level group flow and the level group, find the solution pressure before the revised final stage group of heat regenerative system;
(d) the diagnosis link of flow passage component fouling degree in the middle of the steam turbine at different levels groups, is utilized pressure ratio before and after certain grade of group that step (c) obtains, and in conjunction with the front and back pressure ratio numerical value of this grade group under the design conditions,
That is:
In the formula: a is the index of reflection Turbine Flow Path fouling degree, A
1Be level group flow passage component area after the flow passage component fouling in the actual motion, A is certain grade of group cocurrent flow part area under the Design of Steam Turbine state,
For the Design of Steam Turbine state down in the middle of the ratio of pressure before pressure and the level group after at different levels groups,
Ratio for pressure before at different levels groups of actual measurement levels group back, the revised centre that obtains by step (c) pressure and the level group;
For the final stage group of steam turbine, the steam turbine main steam flow that pressure before the final stage group of utilizing that step (c) obtains and step (b) obtain, and in conjunction with pressure and main steam flow before the final stage group under the design conditions,
That is:
In the formula, G
MsBe the main steam flow under the actual operating mode, G
Ms0Be the main steam flow under the design conditions, p
E1For the steam turbine operation state down through the pressure before the revised final stage group, p
E0Be the pressure before the final stage group under the Design of Steam Turbine state;
Numerical value a has reflected that the flow passage component area behind the turbine fouling accounts for the number percent of former design area, thus quantitative response Turbine Flow Path fouling degree.
Technical scheme provided by the invention can realize Turbine Flow Path fouling early detection and processing in time flow passage component fouling quantitative test by the monitoring to pressure before the level group of the front and back pressure ratio of at different levels groups of Turbine Flow Path and final stage.Have methodological science, can realize the automatic on-line monitoring, advantages such as accuracy of judgement.
Description of drawings
Fig. 1 is a kind of on-line monitoring method flow synoptic diagram of Turbine Flow Path fouling degree.
The hydrophobic surface heater thermal equilibrium synoptic diagram of releasing of Fig. 2.
Fig. 3 contact(-type) heater thermal equilibrium synoptic diagram.
Fig. 4 collective-type well heater thermal equilibrium synoptic diagram.
Fig. 5 feedwater flow balance synoptic diagram.
Fig. 6 determines regenerative steam dot structure synoptic diagram according to steam turbine isentropic expansion process line.
Embodiment
Further specify concrete implementation step of the present invention and computing method below in conjunction with accompanying drawing.As seen from Figure 1, the diagnostic method of through-flow fouling of steam turbine provided by the invention mainly is made up of following several links.
1. data acquisition link is utilized regenerative steam pressure-measuring-points at different levels in the steam turbine operation, measures in the middle of the steam turbine pressure before pressure before and after at different levels groups, the final stage group, and pressure ratios before and after at different levels groups in the middle of calculating.
The present invention needs the monitoring parameter inventory
| Generator end power (KW) | Feed pump A exports water pressure (MPa) |
| Generator power factor (%) | Feed pump A outlet coolant-temperature gage (℃) |
| Main condensate flow (t/h) | Small turbine B initial steam pressure (MPa) |
| Main steam pressure (first) (MPa) before the main inlet throttle-stop valve | Small turbine B throttle (steam) temperature (℃) |
| Main steam temperature (first) before the main inlet throttle-stop valve (℃) | Small turbine B steam consumption (t/h) |
| Main steam pressure (second) (MPa) before the main inlet throttle-stop valve | Small turbine B exhaust steam pressure (KPa) |
| Main steam temperature (second) before the main inlet throttle-stop valve (℃) | Feed pump B inlet water pressure (MPa) |
| Pressure (MPa) behind the 1# high voltage adjusting porthole | Feed pump B inlet water temperature (℃) |
| Pressure (MPa) behind the 2# high voltage adjusting porthole | Feed pump B exports water pressure (MPa) |
| Pressure (MPa) behind the 3# high voltage adjusting porthole | Feed pump B outlet coolant-temperature gage (℃) |
| Pressure (MPa) behind the 4# high voltage adjusting porthole | Low pressure (LP) cylinder initial steam pressure (KPa) |
| Pressure (MPa) behind the 5# high voltage adjusting porthole | The low pressure (LP) cylinder throttle (steam) temperature (℃) |
| Pressure (MPa) behind the 6# high voltage adjusting porthole | The 5th section extraction pressure (MPa) |
| Dome pressure behind the governing stage (MPa) | The 5th section extraction temperature (℃) |
| Steam chest temperature behind the governing stage (℃) | The 6th section extraction pressure (MPa) |
| First section extraction pressure (MPa) | The 6th section extraction temperature (℃) |
| First section extraction temperature (℃) | The 7th section extraction pressure (MPa) |
| High pressure cylinder exhaust steam pressure (MPa) | The 7th section extraction temperature (℃) |
| The high pressure cylinder exhaust temperature (℃) | The 8th section extraction pressure (MPa) |
| Hot colder section pressure (MPa) | The 8th section extraction temperature (℃) |
| Hot colder section temperature (℃) | Condenser vacuum (kPa) |
| The middle preceding vapor pressure (MPa) of connection porthole of pressing | The condenser hotwell condensing water temperature (℃) |
| Reheat steam temperature degree before the middle pressure connection porthole (℃) | Condensate pump outlet coolant-temperature gage (℃) |
| The 3rd section extraction pressure (MPa) | Condensate pump outlet water pressure (℃) |
| The 3rd section extraction temperature (℃) | The shaft sealing cooler inflow temperature (℃) |
| Intermediate pressure cylinder exhaust steam pressure (MPa) | The shaft sealing cooler leaving water temperature (℃) |
| The intermediate pressure cylinder exhaust temperature (℃) | The shaft sealing cooler drain temperature (℃) |
| Small turbine A initial steam pressure (MPa) | Shaft sealing cooler initial steam pressure (MPa) |
| Small turbine A throttle (steam) temperature (℃) | The low initial steam pressure (MPa) that adds of #8 |
| Small turbine A steam consumption (t/h) | #8 is low add throttle (steam) temperature (℃) |
| Feed pump A inlet water pressure (MPa) | #8 is low add leaving water temperature (℃) |
| Feed pump A inlet water temperature (℃) | #8 low plus hydrophobic temperature (℃) |
| The low initial steam pressure (MPa) that adds of #7 | The #2 height add leaving water temperature (℃) |
| #7 is low add throttle (steam) temperature (℃) | The #2 height add drain temperature (℃) |
| #7 is low add leaving water temperature (℃) | The #1 height adds initial steam pressure (MPa) |
| #7 low plus hydrophobic temperature (℃) | The #1 height add throttle (steam) temperature (℃) |
| The low initial steam pressure (MPa) that adds of #6 | The #1 height add leaving water temperature (℃) |
| #6 is low add throttle (steam) temperature (℃) | The #1 height add drain temperature (℃) |
| #6 is low add leaving water temperature (℃) | Feed temperature (℃) the economizer inlet |
| #6 low plus hydrophobic temperature (℃) | Reheater water spray pressure (MPa) |
| The low initial steam pressure (MPa) that adds of #5 | Reheater water spray temperature (℃) |
| #5 is low add throttle (steam) temperature (℃) | Reheater spray flow (t/h) |
| #5 is low add leaving water temperature (℃) | Superheater water spray pressure (MPa) |
| #5 low plus hydrophobic temperature (℃) | Superheater water spray temperature (℃) |
| #4 oxygen-eliminating device initial steam pressure (MPa) | Superheater spray flow (t/h) |
| #4 oxygen-eliminating device throttle (steam) temperature (℃) | Leakage quantity outside the system (t/h) |
| #4 deaerator storage tank temperature (℃) | Main feed pressure (MPa) |
| The #3 height add inflow temperature (℃) | Main condensate pressure (MPa) |
| The #3 height adds initial steam pressure (MPa) | Main steam flow (t/h) |
| The #3 height add throttle (steam) temperature (℃) | Feed-tank water level (mm) |
| The #3 height add leaving water temperature (℃) | Hot well sealing position (mm) |
| The #3 height add drain temperature (℃) | Steam water-level (mm) |
| The #2 height adds initial steam pressure (MPa) | Continuous blowdown system of boiler flow (t/h) |
| The #2 height add throttle (steam) temperature (℃) | Rate of water make-up (t/h) |
Pressure ratio is before and after the level group
Wherein, p
jBe j section regenerative steam pressure, MPa.
2. main steam flow calculates link
(1) calculating of high-pressure heater and oxygen-eliminating device regenerative steam amount
In the heat regenerative system of steam turbine, bleeder heater mainly is divided into surface heater, contact(-type) heater, collective-type well heater three classes.Calculating by the conventional thermal balance equation of above three class well heaters can access heat regenerative system regenerative steam flows at different levels.
Thermal balance equation for certain hydrophobic surface heater of releasing shown in Figure 2 is
η[(h
i-h
s，i)G
i+G
mi(h
mi-h
s，i)+G
s，i+1(h
s，i+1-h
s，i)]＝G
c0(h
i，2-h
i，1) (6)
In the formula, G
C0Be condensate water or the feedwater flow that enters well heater at the corresponding levels, kg/h; G
i, G
MiBe respectively the regenerative steam flow and the auxiliary steam flow that enter well heater at the corresponding levels, kg/h; G
S, i+1For adjacent heater enters the hydrophobic flow of well heater at the corresponding levels, kg/h; h
i, h
MiBe respectively the regenerative steam that enters well heater at the corresponding levels and the enthalpy of auxiliary steam, kJ/kg; h
S, iBe the hydrophobic enthalpy of well heater at the corresponding levels, kJ/kg; h
S, i+1For adjacent heater enters the hydrophobic enthalpy of well heater at the corresponding levels, kJ/kg; h
I, 1, h
I, 2Be respectively the condensate water or the Enthalpy of Feed Water of well heater water side entrance at the corresponding levels and outlet, kJ/kg; η is a heater efficiency at the corresponding levels.
For contact(-type) heater shown in Figure 3, promptly the thermal balance equation of oxygen-eliminating device is
η[(h
i-h
i，0)G
i+G
mi(h
mi-h
i，0)+G
s，i+1(h
s，i+1-h
i，0)]＝Gc(h
i，0-h
i，1) (7)
In the formula, G
cFor entering the condensing water flow of contact(-type) heater, kg/h; h
I, 0For contact(-type) heater goes out saliva enthalpy, kJ/kg.
Thermal balance equation for certain collective-type well heater shown in Figure 4 is
η[(h
i-h
i+1，1)G
i+G
mi(h
mi-h
i+1，1)+G
s，i+1(h
s，i+1-h
i+1，1)]＝G
c1(h
i+1，1-h
i，1) (8)
In the formula, G
C1Be the condensing water flow before the collective-type well heater, kg/h; h
I+1,1For the collective-type heater outlet compiles the enthalpy of water afterwards, kJ/kg.
Like this, obtain the temperature and pressure of well heater vapour sides at different levels and water side import and export working medium by on-line measurement, can obtain vapour, the water enthalpy of well heater import and exports at different levels by means of water and steam character calculation procedure, thereby application formula (6), formula (7) or formula (8), the flow of the regenerative steam of high-pressure heaters at different levels and oxygen-eliminating device when obtaining operation.
(2) main steam flow determines
Carry out steam turbine mass balance and energy equilibrium and calculate, at first need to determine to enter the main steam flow of steam turbine.Because Turbo-generator Set constantly develops to high parameter, high capacity direction, main steam flow constantly increases, the also corresponding increase of the diameter of main steam line, make the difficulty that flow measurement device is installed on main steam line increase, the maintenance of device and calibration are also comparatively difficult, and this has influence on the accuracy of main steam flow measured value.Simultaneously, installing flow measurement device on main steam line additional can increase restriction loss, from also can not being tolerated gradually economically.Therefore, modern big power station trends towards not installing flow measurement device additional at main steam line, and determines the main steam flow that enters steam turbine in service by feedwater flow.
Feedwater flow can directly measure, and this flow measurement device is installed in high-pressure heater and is exported on the feedwater piping between the boiler economizer.But for the high capacity unit, this flow measurement device mostly is and is welded on the feedwater piping, is a kind of nonvolatil device, is not easy to safeguard and check.Therefore, in thermal test standards such as the GB8117-87 of China and the PTC6-1976 of ASME, measured value with the condensing water flow of oxygen-eliminating device inlet is a benchmark, calculates feedwater flow by the heat regenerative system flow equilibrium, and then releases main steam flow.Because the measurement mechanism of oxygen-eliminating device inlet condensing water flow adopts flange to connect more, is convenient to it is checked, changes the standard knot fluid element, meets the requirements to guarantee flow measurement precision in service.Therefore, be that benchmark calculates feedwater flow and main steam flow with flow measurements herein, precision is higher.
Condensing water flow measured value with the oxygen-eliminating device inlet is that benchmark calculates boiler feedwater flow as shown in Figure 5
G
f＝G
c+∑G
i+∑G
mi+G
0+G
m0+G
d1-G
sz-G
zr-G
gr (9)
In the formula, G
f, G
cBe respectively the condensing water flow of boiler feedwater flow and oxygen-eliminating device inlet, kg/h; G
i, G
MiBe respectively the regenerative steam flow and the auxiliary steam flow that enter certain high-pressure heater, kg/h; G
0, G
M0Be respectively the regenerative steam flow and the auxiliary steam flow that enter oxygen-eliminating device, kg/h; G
SzFor flowing out oxygen-eliminating device for the flow of axle envelope with vapour, kg/h; G
ZrBe the flow of reheater desuperheating water, kg/h; G
GrBe the flow of superheater desuperheating water, kg/h; G
D1Be deaerator storage tank SEA LEVEL VARIATION equivalent flow, when water level reduces, get and when, water level raises, get negative value, kg/h.
After considering boiler blow-off, the main steam flow that enters steam turbine just equals boiler feedwater flow and deducts the boiler blow-off amount and add superheater desuperheating water flow, promptly
G
ms＝G
f-G
pw+G
gr (10)
Wherein, G
PwBe boiler blow-off flow, kg/h.
3. heat regenerative system parameter correction link
Steam turbine is under operating condition, and on many links of heat regenerative system, its working condition has departed from the condition of design code.For example, well heater upper and lower side difference off-design value; Superheater and reheater spray water flux are non-vanishing etc.Because the heat regenerative system operation conditions has departed from design load, thereby has influence on the extraction pressure of heat regenerative system, finally has influence on the front and back pressure ratio of each grade group.For these influences are separated, need revise the operational factor of heat regenerative system.
(1) main steam flow equals operating main steam flow.
(2) feedwater flow equals main steam flow, and boiler side is not leaked.
(3) water yield no change in other tanks in condenser hotwell, oxygen-eliminating device and the system, promptly leakage quantity is zero outside the system.
(4) desuperheating water is zero.
(5) extraction line does not have radiation loss, and well heater admission enthalpy is got regenerative steam point enthalpy in service.
(6) the extraction line crushing is got design load.Therefore, the well heater initial steam pressure is the fixed extraction line pressure drop of operating extraction pressure derating.
(7) each heater terminal difference is got design load.Leave the feed temperature of each well heater, for the heater terminal that the saturation temperature derating under the initial steam pressure is fixed poor.If well heater does not comprise hydrophobic cooling section, then the heater condensate temperature equals and the corresponding saturation temperature of well heater vapor pressure.If well heater comprises hydrophobic cooling section, it is poor that then drain temperature equals the lower end that well heater inflow temperature at the corresponding levels adds regulation.The oxygen-eliminating device leaving water temperature is the saturation temperature under the initial steam pressure, and oxygen-eliminating device is zero to empty displacement.The bypass leakage amount of each well heater is zero.
(8) inflow temperature of minimum pressure well heater is got the saturation temperature under the steam turbine exhaust pressure in service, deducts the condenser supercooling degree of regulation, adds the condensate pump temperature rise of regulation.
(9) the flow in the regulation circulation, do not have extra flow person who lives in exile, flow out the circulation system.
(10) get design load by the enthalpy liter of feed pump.
(11) the shaft seal steam parameter is a design load.
(11) exhaust steam pressure of high pressure cylinder keeps runtime value constant.
When carrying out the Steam Turbine Regenerative System corrected Calculation, above-mentioned whole changing factors are combined to be incorporated in each step of corrected Calculation.
(2) calculate revised regenerative steam flows at different levels, each level group front and back pressure ratio
In calculating, gland packing leakage, door bar leak vapour and the shaft seal steam parameter keeps runtime value constant, and the parameter of each regenerative steam point is got runtime value.The exhaust steam pressure of steam turbine high-pressure cylinder and low pressure (LP) cylinder adopts runtime value in system's corrected Calculation.Adopt the pairing heat balance equation of Fig. 2-Fig. 5 (6)-Shi (8), obtain revised regenerative steam amount at different levels.In calculating regenerative steam amount process, the regenerative steam point get as shown in Figure 6 employing regenerative steam pressure line and the focus of steam thermal procession line during isentropic expansion in steam turbine determine, be difficult to the problem accurately determined thereby avoided condensing turbine thermal procession line.According to revised regenerative steam flows at different levels, obtain the steam flow of revised Turbine Flow Path, it no longer equals the flow under the operating condition, and then the pressure before and after each grade group also will change.Revised regenerative steam calculation of pressure adopts the Fu Liugeer formula of knowing to calculate, according to the principle of being calculated forward by the turbine discharge end.
Meet or exceed 1% if revised each regenerative steam pressure is level group front and back pressure and runtime value relative deviation, then need gland packing leakage to be revised according to the pressure that newly obtains.Simultaneously, regenerative steam pressure adopts each section regenerative steam pressure that newly obtains.Repeat above-mentioned computation process again, until the regenerative steam pressure relative deviation that obtains for adjacent twice less than 1%.
4. the diagnosis link of Turbine Flow Path fouling degree
Revised each section regenerative steam pressure that above-mentioned each link is obtained, can obtain before and after at different levels groups of the revised centres pressure ratio and the preceding pressure of final stage group, substitution formula (2) and formula (4) promptly can realize the quantitative Diagnosis to Turbine Flow Path fouling degree respectively.
5. the example of Turbine Flow Path fouling degree diagnosis
Homemade 300MW steam turbine intergrade group, the front and back pressure ratio under the design conditions is 0.539, and pressure ratio is 0.512 before and after the actual measurement in service, and pressure ratio is 0.510 before and after the revised level group.Bringing formula (2) into calculates
As seen, this stage group flow passage component fouling is serious, makes the Turbine Flow Path area reduce 6.11%.Proved validity of the present invention according to example.
Claims (1)
1. the on-line monitoring method of a Turbine Flow Path fouling degree is characterized in that it may further comprise the steps:
(a) data acquisition link is utilized regenerative steam pressure-measuring-points at different levels in the steam turbine operation, measures in the middle of the steam turbine pressure before pressure before and after at different levels groups, the final stage group, and pressure ratios before and after at different levels groups in the middle of calculating;
(b) main steam flow calculates link, by calculating to the regenerative steam amount of each high-pressure heater and oxygen-eliminating device, and utilize oxygen-eliminating device inlet condensing water flow table meter, and consider reheater, superheater desuperheating water flow and boiler blow-off amount simultaneously, determine the main steam flow of steam turbine;
(c) heat regenerative system parameter correction link, based on steam turbine isentropic expansion process line, the backheat bleed off passage is all got the intersection point between isentropic expansion process and the corresponding regenerative steam pressure, determine the regenerative steam amount that steam turbine waits until that entropy expands, utilize the Fu Liugeer formula to find the solution the front and back pressure ratio of at different levels groups of revised centres, utilize the proportional principle of pressure before level group flow and the level group, find the solution pressure before the revised final stage group of heat regenerative system;
(d) the diagnosis link of flow passage component fouling degree in the middle of the steam turbine at different levels groups, is utilized pressure ratio before and after certain grade of group that step (c) obtains, and in conjunction with the front and back pressure ratio numerical value of this grade group under the design conditions,
That is:
In the formula: a is the index of reflection Turbine Flow Path fouling degree, A
1Be level group flow passage component area after the flow passage component fouling in the actual motion, A is certain grade of group cocurrent flow part area under the Design of Steam Turbine state,
For the Design of Steam Turbine state down in the middle of the ratio of pressure before pressure and the level group after at different levels groups,
Ratio for pressure before at different levels groups of actual measurement levels group back, the revised centre that obtains by step (c) pressure and the level group;
For the final stage group of steam turbine, the steam turbine main steam flow that pressure before the final stage group of utilizing that step (c) obtains and step (b) obtain, and in conjunction with pressure and main steam flow before the final stage group under the design conditions,
That is:
In the formula, G
MsBe the main steam flow under the actual operating mode, G
Ms0Be the main steam flow under the design conditions, p
E1For the steam turbine operation state down through the pressure before the revised final stage group, p
E0Be the pressure before the final stage group under the Design of Steam Turbine state; Numerical value a has reflected that the flow passage component area behind the turbine fouling accounts for the number percent of former design area, thus quantitative response Turbine Flow Path fouling degree.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN 201010564644 CN102004460A (en) | 2010-11-24 | 2010-11-24 | Online monitoring method for fouling degree of flow passage of steam turbine |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN 201010564644 CN102004460A (en) | 2010-11-24 | 2010-11-24 | Online monitoring method for fouling degree of flow passage of steam turbine |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN102004460A true CN102004460A (en) | 2011-04-06 |
Family
ID=43811884
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN 201010564644 Pending CN102004460A (en) | 2010-11-24 | 2010-11-24 | Online monitoring method for fouling degree of flow passage of steam turbine |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN102004460A (en) |
Cited By (17)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102252809A (en) * | 2011-06-14 | 2011-11-23 | 山东泓奥电力科技有限公司 | Method for diagnosing state of flow path shaft seal system of steam turbine |
| CN103091123A (en) * | 2013-01-09 | 2013-05-08 | 北京世纪源博科技股份有限公司 | Ranking cycle cold source device and vacuum breakdown self diagnosis method |
| CN105781632A (en) * | 2016-02-26 | 2016-07-20 | 上海发电设备成套设计研究院 | Monitoring for total calendar life of turbine part under low-cycle fatigue and creep effect |
| CN106124119A (en) * | 2016-08-01 | 2016-11-16 | 中国神华能源股份有限公司 | Steam turbine extraction pressure flexible measurement method |
| CN106570237A (en) * | 2016-10-25 | 2017-04-19 | 浙江理工大学 | Method and system for monitoring stator blade thickness of turbine of blast furnace gas waste heat recovery device |
| CN106682376A (en) * | 2017-04-01 | 2017-05-17 | 国网河南省电力公司电力科学研究院 | Whole-process steam turbine modeling and recognizing method of actual characteristics of parameters changing with working conditions |
| CN106908249A (en) * | 2017-02-27 | 2017-06-30 | 西安热工研究院有限公司 | A kind of abnormal diagnostic method of through-flow stage efficiency of steam turbine high-pressure cylinder |
| CN107907005A (en) * | 2017-10-12 | 2018-04-13 | 国网河北能源技术服务有限公司 | A kind of monitoring method of direct air cooled condenser fin heat-transfer surface clean conditions |
| CN109372595A (en) * | 2018-08-23 | 2019-02-22 | 哈尔滨汽轮机厂有限责任公司 | The online damage state assessment system of turbine blade and turbine blade lifetime estimation method |
| CN110332911A (en) * | 2019-06-17 | 2019-10-15 | 中科宏声(苏州)声学科技有限公司 | Using the measurement method of steam condenser vacuum measurement heat exchanging pipe fouling thickness |
| CN111365083A (en) * | 2020-04-10 | 2020-07-03 | 西安热工研究院有限公司 | Thermal parameter-based turbine through-flow part fault diagnosis method |
| CN111441831A (en) * | 2020-03-03 | 2020-07-24 | 大唐东北电力试验研究院有限公司 | Minimum safe flow test method for steam turbine |
| CN112052633A (en) * | 2020-08-28 | 2020-12-08 | 吉林省电力科学研究院有限公司 | Method for determining turbine last-stage blade shedding height under small volume flow |
| CN112485011A (en) * | 2020-10-26 | 2021-03-12 | 华北电力科学研究院有限责任公司 | Method, device and equipment for determining salt accumulation condition |
| CN113176081A (en) * | 2021-03-03 | 2021-07-27 | 中国大唐集团科学技术研究院有限公司火力发电技术研究院 | Historical data-based turbine blade wear monitoring method |
| CN113218596A (en) * | 2021-04-29 | 2021-08-06 | 中电华创电力技术研究有限公司 | Leakage detection method and device for #4 low-pressure heater of coal-fired generator set |
| CN114543724A (en) * | 2022-01-11 | 2022-05-27 | 国能浙江宁海发电有限公司 | Condenser scaling thickness testing method |
-
2010
- 2010-11-24 CN CN 201010564644 patent/CN102004460A/en active Pending
Non-Patent Citations (4)
| Title |
|---|
| 《东北电力大学学报(自然科学版)》 20080415 张毅等 汽轮机通流部分结垢变化特征参数提取 , 第02期 * |
| 《动力工程》 19950215 郝志莉，叶春 电站汽轮机组通流部分故障分析及诊断 , 第01期 * |
| 《汽轮机技术》 19931010 张洪奎 汽轮机通流截面缩小的故障诊断及处理 , 第05期 * |
| 《浙江电力》 20001028 毛志伟等 汽轮机通流部分故障的特性分析及仿真计算 , 第05期 * |
Cited By (26)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102252809A (en) * | 2011-06-14 | 2011-11-23 | 山东泓奥电力科技有限公司 | Method for diagnosing state of flow path shaft seal system of steam turbine |
| CN103091123A (en) * | 2013-01-09 | 2013-05-08 | 北京世纪源博科技股份有限公司 | Ranking cycle cold source device and vacuum breakdown self diagnosis method |
| CN103091123B (en) * | 2013-01-09 | 2015-08-05 | 北京世纪源博科技股份有限公司 | A kind of Rankine cycle cold source device with vacuum failure self-diagnostic function |
| CN105781632A (en) * | 2016-02-26 | 2016-07-20 | 上海发电设备成套设计研究院 | Monitoring for total calendar life of turbine part under low-cycle fatigue and creep effect |
| CN105781632B (en) * | 2016-02-26 | 2017-09-26 | 上海发电设备成套设计研究院 | The monitoring of components of steam turbine calendar entire life in the case where low-cycle fatigue and creep are acted on |
| CN106124119B (en) * | 2016-08-01 | 2019-02-12 | 中国神华能源股份有限公司 | Steam turbine extraction pressure flexible measurement method |
| CN106124119A (en) * | 2016-08-01 | 2016-11-16 | 中国神华能源股份有限公司 | Steam turbine extraction pressure flexible measurement method |
| CN106570237A (en) * | 2016-10-25 | 2017-04-19 | 浙江理工大学 | Method and system for monitoring stator blade thickness of turbine of blast furnace gas waste heat recovery device |
| CN106570237B (en) * | 2016-10-25 | 2020-03-17 | 浙江理工大学 | Turbine stator blade thickness monitoring method and system of blast furnace gas waste heat recovery device |
| CN106908249A (en) * | 2017-02-27 | 2017-06-30 | 西安热工研究院有限公司 | A kind of abnormal diagnostic method of through-flow stage efficiency of steam turbine high-pressure cylinder |
| CN106682376A (en) * | 2017-04-01 | 2017-05-17 | 国网河南省电力公司电力科学研究院 | Whole-process steam turbine modeling and recognizing method of actual characteristics of parameters changing with working conditions |
| CN106682376B (en) * | 2017-04-01 | 2020-03-10 | 国网河南省电力公司电力科学研究院 | Whole-process steam turbine modeling and identification method for actual characteristics of parameters changing along with working conditions |
| CN107907005A (en) * | 2017-10-12 | 2018-04-13 | 国网河北能源技术服务有限公司 | A kind of monitoring method of direct air cooled condenser fin heat-transfer surface clean conditions |
| CN109372595A (en) * | 2018-08-23 | 2019-02-22 | 哈尔滨汽轮机厂有限责任公司 | The online damage state assessment system of turbine blade and turbine blade lifetime estimation method |
| CN109372595B (en) * | 2018-08-23 | 2021-05-07 | 哈尔滨汽轮机厂有限责任公司 | On-line damage state evaluation system for turbine blade and service life evaluation method for turbine blade |
| CN110332911A (en) * | 2019-06-17 | 2019-10-15 | 中科宏声(苏州)声学科技有限公司 | Using the measurement method of steam condenser vacuum measurement heat exchanging pipe fouling thickness |
| CN111441831A (en) * | 2020-03-03 | 2020-07-24 | 大唐东北电力试验研究院有限公司 | Minimum safe flow test method for steam turbine |
| CN111365083A (en) * | 2020-04-10 | 2020-07-03 | 西安热工研究院有限公司 | Thermal parameter-based turbine through-flow part fault diagnosis method |
| CN112052633A (en) * | 2020-08-28 | 2020-12-08 | 吉林省电力科学研究院有限公司 | Method for determining turbine last-stage blade shedding height under small volume flow |
| CN112052633B (en) * | 2020-08-28 | 2022-09-06 | 吉林省电力科学研究院有限公司 | Method for determining turbine last-stage blade shedding height under small volume flow |
| CN112485011A (en) * | 2020-10-26 | 2021-03-12 | 华北电力科学研究院有限责任公司 | Method, device and equipment for determining salt accumulation condition |
| CN113176081A (en) * | 2021-03-03 | 2021-07-27 | 中国大唐集团科学技术研究院有限公司火力发电技术研究院 | Historical data-based turbine blade wear monitoring method |
| CN113218596A (en) * | 2021-04-29 | 2021-08-06 | 中电华创电力技术研究有限公司 | Leakage detection method and device for #4 low-pressure heater of coal-fired generator set |
| CN113218596B (en) * | 2021-04-29 | 2023-09-05 | 中电华创电力技术研究有限公司 | Leakage detection method and device for #4 low-pressure heater of coal-fired power generation unit |
| CN114543724A (en) * | 2022-01-11 | 2022-05-27 | 国能浙江宁海发电有限公司 | Condenser scaling thickness testing method |
| CN114543724B (en) * | 2022-01-11 | 2023-08-22 | 国能浙江宁海发电有限公司 | Condenser scaling thickness testing method |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN102004460A (en) | Online monitoring method for fouling degree of flow passage of steam turbine | |
| CN100437015C (en) | On-line monitoring method for variation of through-flow gap of steam turbine | |
| CN104048842B (en) | A kind of thermal loss of steam turbine rate on-line monitoring method based on soft-measuring technique | |
| CN101825502B (en) | Effluent and drain temperature measurement and calculation method of heater with drain cooler on steam turbine | |
| CN108181099B (en) | A kind of nuclear reactor pressurizer safety valve leak test by filling water system and its test method | |
| CN107201921B (en) | Steam turbine heat consumption rate online monitoring system and measuring method | |
| CN107543733A (en) | A kind of condenser duty on-line monitoring system and measuring method | |
| CN105527113B (en) | A kind of nuclear power station heat energy efficiency monitoring and fault diagnosis system and method | |
| CN111079302A (en) | Low-pressure cylinder efficiency measuring and calculating system and method | |
| CN103063436A (en) | Turbine heat consumption rate index calculation result judgment method | |
| CN108446465B (en) | Method for measuring and calculating steam quantity for thermal power plant on line through working medium decomposition | |
| CN111400875B (en) | Steam turbine unit operation economy evaluation method and system | |
| JP5148535B2 (en) | Steam turbine equipment | |
| CN109709911B (en) | On-line measuring method and system for leakage of circulating working medium of thermal power generating unit | |
| CN100368779C (en) | Safety on-line monitor for water circulation of boiler | |
| CN112326252B (en) | Method for reducing uncertainty of performance test of steam turbine | |
| CN101825503A (en) | Effluent and drain temperature measurement and calculation method of steam turbine surface-type heater | |
| CN104459542A (en) | Heat rate measurement method for reheating regeneration combined cycle unit | |
| CN101852658B (en) | Method for measuring and calculating temperature of effluent and drain from heater with steam cooler and drain cooler of steam engine | |
| CN207623031U (en) | A kind of condenser duty on-line monitoring system | |
| CN113221477B (en) | Heat balance calculation method for determining circulating water flow | |
| CN101832545B (en) | Method for measuring temperatures of out-flowing water and discharged water of heater of turbine steam cooler | |
| CN113569497B (en) | Soft measurement method for condenser cooling water flow | |
| CN206917683U (en) | A kind of thermal loss of steam turbine rate on-line monitoring system | |
| CN215338770U (en) | No. 3 high pressure feed water heater of steam turbine leaks collection system and system |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| C10 | Entry into substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| C02 | Deemed withdrawal of patent application after publication (patent law 2001) | ||
| WD01 | Invention patent application deemed withdrawn after publication |
Application publication date: 20110406 |