Steam turbine operation. Steam Turbine Manual Steam Fri 80
Introduction
For large plants of all industries with high heat consumption, the optimal system of energy supply is from a district or industrial CHP.
The process of generating electricity at CHP plants is characterized by increased thermal efficiency and higher energy performance compared to condensing power plants. This is explained by the fact that the waste heat of the turbine, which is diverted to a cold source (a heat receiver from an external consumer), is used in it.
In the work, the calculation of the thermal scheme of the power plant based on the production heat-and-power turbine PT-80/100-130/13, operating in the design mode at outdoor air temperature, is made.
The task of calculating the thermal scheme is to determine the parameters, costs and directions of the flow of the working fluid in units and units, as well as the total steam consumption, electric power and indicators of the thermal efficiency of the station.
Description of the principal thermal diagram of the PT-80/100-130/13 turbine plant
The 80 MW electric power unit consists of a drum boiler high pressure E-320/140, turbines PT-80/100-130/13, generator and auxiliary equipment.
The power unit has seven selections. It is possible to carry out two-stage heating of network water in the turbine plant. There is a main and peak boiler, as well as a PVC, which turns on if the boilers cannot provide the required heating of the network water.
Fresh steam from the boiler with a pressure of 12.8 MPa and a temperature of 555 0 C enters the turbine HPC and, after exhausting, is sent to the turbine CSD, and then to the LPC. Having worked out, the steam flows from the LPC to the condenser.
The power unit for regeneration has three high-pressure heaters (HPH) and four low-pressure heaters (LPH). The heaters are numbered from the tail of the turbine unit. The condensate of the heating steam HPH-7 is cascaded into HPH-6, into HPH-5 and then into the deaerator (6 atm). Condensate drain from LPH4, LPH3 and LPH2 is also carried out in cascade in LPH1. Then, from the LPH1, the condensate of the heating steam is sent to the CM1 (see PRT2).
The main condensate and feed water are heated sequentially in PE, SH and PS, in four heaters low pressure(HDPE), in a deaerator of 0.6 MPa and in three high pressure heaters (HPE). Steam is supplied to these heaters from three adjustable and four unregulated turbine steam extractions.
The block for heating water in the heating network has a boiler plant, consisting of a lower (PSG-1) and an upper (PSG-2) network heaters, fed respectively with steam from the 6th and 7th selections, and PVK. Condensate from the upper and lower network heaters is supplied by drain pumps to mixers SM1 between LPH1 and LPH2 and SM2 between heaters LPH2 and LPH3.
The feed water heating temperature lies within (235-247) 0 С and depends on the initial pressure of fresh steam, the amount of subheating in HPH7.
The first steam extraction (from HPC) is used to heat feed water in HPH-7, the second steam extraction (from HPC) - to HPH-6, the third (from HPC) - to HPH-5, D6ata, for production; the fourth (from CSD) - in LPH-4, the fifth (from CSD) - in LPH-3, the sixth (from CSD) - in LPH-2, deaerator (1.2 atm), in PSG2, in PSV; the seventh (from CND) - in PND-1 and PSG1.
To make up for losses, a fence is provided in the scheme raw water. Raw water is heated in the raw water heater (RWS) to a temperature of 35 ° C, then, after passing chemical treatment, enters the deaerator 1.2 ata. To provide heating and deaeration additional water the heat of steam from the sixth extraction is used.
Steam from the sealing rods in the amount of D pcs = 0.003D 0 goes to the deaerator (6 atm). Steam from the extreme seal chambers is directed to the SH, from the middle seal chambers to the PS.
Boiler blowdown - two-stage. Steam from the expander of the 1st stage goes to the deaerator (6 atm), from the expander of the 2nd stage to the deaerator (1.2 atm). Water from the expander of the 2nd stage is supplied to the network water main, to partially replenish network losses.
Figure 1. Schematic diagram of a thermal power plant based on TU PT-80/100-130/13
Heating steam turbine PT-80/100-130/13 with industrial and heating steam extraction is designed for direct drive electric generator TVF-120-2 with a rotation speed of 50 rpm and heat supply for the needs of production and heating.
The nominal values of the main parameters of the turbine are given below.
Power, MW
nominal 80
maximum 100
Rated steam parameters
pressure, MPa 12.8
temperature, 0 С 555
Consumption of extracted steam for production needs, t/h
nominal 185
maximum 300
Limits of steam pressure change in controlled heating extraction, MPa
upper 0.049-0.245
lower 0.029-0.098
Production selection pressure 1.28
Water temperature, 0 C
nutritional 249
cooling 20
Cooling water consumption, t/h 8000
The turbine has the following adjustable steam extractions:
production with an absolute pressure (1.275 0.29) MPa and two heating selections - the upper one with an absolute pressure in the range of 0.049-0.245 MPa and the lower one with a pressure in the range of 0.029-0.098 MPa. The heating extraction pressure is regulated by means of one control diaphragm installed in the upper heating extraction chamber. Regulated pressure in the heating outlets is maintained: in the upper outlet - when both heating outlets are turned on, in the lower outlet - when one lower heating outlet is turned on. Network water through the network heaters of the lower and upper stages of heating must be passed sequentially and in equal quantities. The flow of water passing through the network heaters must be controlled.
The turbine is a single-shaft two-cylinder unit. The HPC flow path has a single-row control stage and 16 pressure stages.
The flow part of the LPC consists of three parts:
the first (up to the upper heating outlet) has a control stage and 7 pressure stages,
the second (between the heating taps) two pressure stages,
the third - the control stage and two pressure stages.
The high pressure rotor is one-piece forged. The first ten disks of the low-pressure rotor are forged integrally with the shaft, the remaining three disks are mounted.
The steam distribution of the turbine is nozzle. At the exit from the HPC, part of the steam goes to controlled production extraction, the rest goes to the LPC. Heating extractions are carried out from the corresponding LPC chambers.
To reduce the warm-up time and improve start-up conditions, steam heating of flanges and studs and live steam supply to the HPC front seal are provided.
The turbine is equipped with a barring device that rotates the shafting of the turbine unit at a frequency of 3.4 rpm.
The turbine blade apparatus is designed to operate at a mains frequency of 50 Hz, which corresponds to a turbine rotor speed of 50 rpm (3000 rpm). Allowed long work turbines with a frequency deviation in the network of 49.0-50.5 Hz.
I N S T R U K T I A
PT-80/100-130/13 LMZ.
Instructions must be known:
1. head of the boiler and turbine shop-2,
2. Deputy Heads of the Boiler Turbine Shop for Operation-2,
3. senior shift supervisor of station-2,
4. station shift supervisor-2,
5. shift supervisor of the turbine department of the boiler-turbine shop-2,
6. TsTSHU driver steam turbines VI category,
7. engineer-crawler for turbine equipment of the 5th category;
8. engineer-crawler for turbine equipment of the IV category.
Petropavlovsk-Kamchatsky
JSC Energy and Electrification "Kamchatskenergo".
Branch "Kamchatskiye TPP".
APPROVE:
Chief Engineer branch of JSC "Kamchatskenergo" KTETs
Bolotenyuk Yu.N.
“ “ 20 y.
I N S T R U K T I A
Operating Instructions steam turbine
PT-80/100-130/13 LMZ.
Instruction expiration date:
with "____" ____________ 20
by "____" ____________ 20
Petropavlovsk - Kamchatsky
1. General Provisions…………………………………………………………………… 6
1.1. Criteria for the safe operation of a steam turbine PT80/100-130/13………………. 7
1.2. Turbine technical data……………………………………………………………...…….. 13
1.4. Turbine protection………………………………………………………………….……………… 18
1.5. Turbine must be emergency shutdown with manual vacuum failure…………...... 22
1.6. The turbine must be stopped immediately…………………………………………...… 22
The turbine must be unloaded and stopped within the period
determined by the chief engineer of the power plant……………………………..……..… 23
1.8. Continuous operation of the turbine with rated power is allowed…………………... 23
2. Short description turbine design…………………………………..… 23
3. Turbine unit oil supply system…………………………………..…. 25
4. Generator shaft sealing system……………………………………....… 26
5. Turbine control system…………………………………………...…. 30
6. Technical data and description of the generator……………………………….... 31
7. Technical characteristics and description of the condensing unit…. 34
8. Description and technical specifications regenerative plant…… 37
Description and technical characteristics of the installation for
heating of network water………………………………………………………...… 42
10. Preparation of the turbine unit for start-up………………………………………….… 44
10.1. General Provisions……………………………………………………………………………...….44
10.2. Preparing to put the oil system into operation…………………………………...…….46
10.3. Preparing the control system for start-up………………………………………………..…….49
10.4. Preparation and start-up of the regenerative and condensing unit……………………………49
10.5. Preparing for the inclusion in the operation of the installation for heating network water………………..... 54
10.6. Warming up the steam pipeline to the GPP…………………………………………………………………….....55
11. Starting the turbine unit……………………………………………………………..… 55
11.1. General instructions…………………………………………………………………………………….55
11.2. Starting the turbine from a cold state…………………………………………………………...61
11.3. Starting the turbine from a warm state…………………………………………………….…..64
11.4. Starting the turbine from a hot state……………………………………………………………..65
11.5. Features of turbine start-up on sliding parameters of live steam………………….…..67
12. Turning on the production steam extraction………………………………... 67
13. Shutdown of production steam extraction…………………………….… 69
14. Turning on the heating steam extraction……………………………..…. 69
15. Shutdown of heating steam extraction………………………….…... 71
16. Maintenance of the turbine during normal operation………………….… 72
16.1 General Provisions………………………………………………………………………………….72
16.2 Maintenance of the condensing unit…………………………………………………..74
16.3 Maintenance of the regenerative plant…………………………………………………….….76
16.4 Maintenance of the oil supply system……………………………………………………...87
16.5 Generator maintenance ................................................................................. 79
16.6 Maintenance of the installation for heating network water…………………………………….……80
17. Turbine shutdown…………………………………………………………………… 81
17.1 General instructions for stopping the turbine……………………………………………………….……81
17.2 Shutdown of the turbine in reserve, as well as for repairs without cooling down……………………..…82
17.3 Turbine shutdown for repair with cooldown………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………………
18. Safety requirements…………………………………….…… 86
19. Measures to prevent and eliminate accidents at the turbine ...... 88
19.1. General instructions…………………………………………………………………………………………88
19.2. Cases of emergency shutdown of the turbine…………………………………………………………...…90
19.3. Actions performed by the technological protection of the turbine………………………………………91
19.4. Actions of personnel in case of emergency on the turbine………………………………..…….92
20. Rules for admission to equipment repair……………………………….… 107
21. The procedure for admission to turbine testing………………………………….. 108
Applications
22.1. Turbine start-up schedule from a cold state (metal temperature
HPC in the steam inlet zone less than 150 ˚С)……………………………………………………..… 109
22.2. Turbine start-up schedule after 48 hours of inactivity (metal temperature
HPC in the steam inlet zone 300 ˚С)…………………………………………………………………..110
22.3. Turbine start-up schedule after 24 hours of inactivity (metal temperature
HPC in the steam inlet zone 340 ˚С)……………………………………………………………..…111
22.4. Turbine start-up schedule after 6-8 hours of downtime (metal temperature
HPC in the steam inlet zone 420 ˚С)………………………………………………………………….112
22.5. Turbine start-up schedule after 1-2 hours of downtime (metal temperature
HPC in the steam inlet zone 440 ˚С)……………………………………………………..…………113
22.6. Approximate turbine start-up schedules at nominal
fresh steam parameters……………………………………………………………………….…114
22.7. Longitudinal section of the turbine………………………………………………………………..….…115
22.8. Turbine control scheme……………………………………………………………..….116
22.9. Thermal diagram of the turbine plant……………………………………………………………….….118
23. Additions and changes…………………………………………………...…. 119
GENERAL PROVISIONS.
Steam turbine type PT-80/100-130/13 LMZ with industrial and 2-stage heating steam extraction, rated power 80 MW and maximum 100 MW (in a certain combination of adjustable extractions) is designed for direct generator drive alternating current TVF-110-2E U3 with a capacity of 110 MW, mounted on a common foundation with a turbine.
List of abbreviations and symbols:
AZV - automatic high pressure shutter;
VPU - barring device;
GMN - main oil pump;
GPZ - main steam valve;
KOS - check valve with a servomotor;
KEN - condensate electric pump;
MUT - turbine control mechanism;
OM - power limiter;
PVD - high pressure heaters;
HDPE - low pressure heaters;
PMN - starting oil electric pump;
PN - seal steam cooler;
PS - seal vapor cooler with ejector;
PSG-1 - network heater of the lower selection;
PSG-2 - the same, top selection;
PEN - nutritious electric pump;
RVD - high pressure rotor;
RK - control valves;
RND - low pressure rotor;
RT - turbine rotor;
HPC - high pressure cylinder;
LPC - low pressure cylinder;
RMN - reserve oil pump;
AMN - emergency oil pump;
RPDS - oil pressure drop switch in the lubrication system;
Рpr - steam pressure in the production selection chamber;
P - pressure in the chamber of the lower heating extraction;
P - the same, upper heating selection;
Dpo - steam consumption in the production selection;
D - total consumption for PSG-1.2;
KAZ - automatic shutter valve;
MNUV - generator shaft seal oil pump;
NOG - generator cooling pump;
SAR - automatic control system;
EGP - electrohydraulic converter;
KIS - executive solenoid valve;
TO - heating selection;
ON - production selection;
MO - oil cooler;
RPD - differential pressure regulator;
PSM - mobile oil separator;
ЗГ - hydraulic shutter;
BD - damper tank;
IM - oil injector;
RS - speed controller;
RD - pressure regulator.
1.1.1. Turbine power:
Maximum turbine power at full power
regeneration and certain combinations of production and
heating extraction …………………………………………………………………...100 MW
Maximum turbine power in condensing mode with HPH-5, 6, 7 off
Maximum power of the turbine in the condensing mode with LPH-2, 3, 4 off ……………………………………………………………………....71MW
The maximum power of the turbine in condensing mode with
LPH-2, 3, 4 and PVD-5, 6, 7 …………………………………………………………………………….68 MW
which are included in the operation of PVD-5,6,7………………………………………………………..10 MW
The minimum power of the turbine in condensing mode at
which the drain pump PND-2 is switched on……………………………………………….20 MW
The minimum power of the turbine unit at which are included in
operation of adjustable turbine extractions……………………………………………………………… 30 MW
1.1.2. According to the frequency of rotation of the turbine rotor:
Rated turbine rotor speed ……………………………………………..3000 rpm
Rated speed of the turbine rotor barring
device ………………………………………………………………………………..………..3.4 rpm
Maximum deviation of the turbine rotor speed at
which the turbine unit is switched off by the protection……………………………………….………..…..3300 rpm
3360 rpm
The critical speed of the turbogenerator rotor …………………………………….1500 rpm
Critical speed of low pressure turbine rotor…………………….……1600 rpm
The critical speed of the turbine high pressure rotor…………………….….1800 rpm
1.1.3. According to the flow of superheated steam to the turbine:
Nominal steam flow to the turbine when operating in condensing mode
with a fully activated regeneration system (at rated power
turbine unit equal to 80 MW) ………………………………………………………………305 t/h
Maximum steam flow to the turbine with the system turned on
regeneration, controlled production and heat extraction
and closed control valve No. 5 …..……………………………………………………..415 t/h
Maximum steam consumption per turbine …………………….…………………..………………470 t/h
mode with disabled HPH-5, 6, 7 …………………………………………………………..270 t/h
The maximum steam flow to the turbine during its operation on the condensing
mode with disabled LPH-2, 3, 4 ……………………………………………………………..260t/h
The maximum steam flow to the turbine during its operation on the condensing
mode with disabled LPH-2, 3, 4 and PVD-5, 6, 7………………………………………..…230t/h
1.1.4. According to the absolute pressure of superheated steam in front of the CBA:
Nominal absolute pressure of superheated steam before CBA…………………..……….130 kgf/cm 2
Permissible reduction in the absolute pressure of superheated steam
before CBA during turbine operation…….………………………………………………………………125 kgf/cm 2
Permissible increase in the absolute pressure of superheated steam
before CBA during turbine operation.…………………………………………………………………135 kgf/cm 2
The maximum deviation of the absolute pressure of superheated steam before the CBA
during operation of the turbine and with the duration of each deviation not more than 30 minutes……..140 kgf/cm 2
1.1.5. According to the superheated steam temperature in front of the CBA:
Nominal temperature of superheated steam before CBA..…………………………………..…..555 0 С
Permissible drop in superheated steam temperature
before CBA during turbine operation..…………………………………………………………….……… 545 0 С
Permissible rise in superheated steam temperature before
CBA during turbine operation…………………………………………………………………………….. 560 0 С
The maximum deviation of the superheated steam temperature in front of the CBA at
operation of the turbine and the duration of each deviation is not more than 30
minutes………………….………………..…………………………………………………….………565 0 С
The minimum deviation of the superheated steam temperature in front of the CBA at
which the turbine unit is switched off by the protection………………………………………………………...425 0 С
1.1.6. According to the absolute steam pressure in the control stages of the turbine:
at superheated steam flow rates for the turbine up to 415 t/h. ..……………………………………...98.8 kgf / cm 2
Maximum absolute steam pressure in HPC control stage
when the turbine is operating in the condensing mode with disabled HPH-5, 6, 7….……….…64 kgf/cm 2
Maximum absolute steam pressure in HPC control stage
when the turbine is operating in condensing mode with LPH-2, 3, 4 off ………….…62 kgf/cm 2
Maximum absolute steam pressure in HPC control stage
when the turbine is operating in condensing mode with LPH-2, 3, 4 turned off
and PVD-5, 6.7……………………………………………………………………..……….……… .....55 kgf / cm 2
The maximum absolute steam pressure in the refueling chamber
HPC valve (behind the 4-stage) at superheated steam flow rates to the turbine
more than 415 t/h ……………………………………………………………………………………………………………83 kgf/cm 2
Maximum absolute steam pressure in the control chamber
LPC stages (behind the 18th stage) ……………………………..……………………………………..13.5 kgf / cm 2
1.1.7. According to the absolute steam pressure in the controlled turbine extractions:
Permissible increase in absolute steam pressure in
controlled production selection ………………………………………………………… 16 kgf / cm 2
Permissible reduction in absolute steam pressure in
controlled production selection …………………………………………………………… 10 kgf / cm 2
The maximum deviation of the absolute steam pressure in the controlled production extraction at which the safety valves……………………………………………………………………..19.5 kgf / cm 2
upper heating extraction ………………………………………………………….…..2.5 kgf/cm 2
upper heating extraction ………………………………………………………..……..0.5 kgf/cm 2
The maximum deviation of the absolute steam pressure in the regulated
upper heating extraction at which it works
safety valve…………………………………………………………………..……3.4 kgf/cm2
The maximum deviation of the absolute steam pressure in
controlled upper heating extraction, in which
the turbine unit is switched off by the protection……………………………………………..…………………...3.5 kgf/cm 2
Permissible increase in the absolute steam pressure in the regulated
lower heating extraction ………………………………………………………….…… 1 kgf / cm 2
Permissible reduction in the absolute steam pressure in the regulated
lower heating extraction ……………………………………………………………….…0.3 kgf/cm 2
Maximum allowable pressure drop between the chamber
lower heating extraction and turbine condenser………………………….… up to 0.15 kgf/cm 2
1.1.8. According to the steam flow in the controlled turbine extractions:
Nominal steam flow in an adjustable production
selection ………………………………………………………………………………………….……185 t/h
Maximum steam flow in an adjustable production…
rated power of the turbine and disconnected
heating extraction ……………………………………………………………….………245 t/h
The maximum steam flow in an adjustable production
selection at an absolute pressure in it equal to 13 kgf / cm 2,
turbine power reduced to 70 MW and switched off
heating extraction …………………………………………………………………..……300 t/h
Nominal steam flow in adjustable top
heat extraction ………………………………………………………………………...132 t/h
and disconnected production sampling ………………………………………………………………………………………150 t/h
Maximum steam flow in adjustable top
heat extraction with power reduced to 76 MW
turbine and disconnected production extraction ……………………………………….……220 t/h
Maximum steam flow in adjustable top
heat extraction at rated turbine power
and reduced to 40 t/h steam consumption in production extraction ……………………………200 t/h
Maximum steam consumption in PSG-2 at absolute pressure
in the upper heating extraction 1.2 kgf/cm 2 …………………………………………….…145 t/h
Maximum steam consumption in PSG-1 at absolute pressure
in the lower heating extraction 1 kgf / cm 2 ………………………………………………….220 t/h
1.1.9. According to the steam temperature in the turbine extractions:
Nominal steam temperature in a controlled production
selection after OU-1, 2 (3.4) …………………………………………………………………………..280 0 С
Permissible rise in steam temperature in controlled
production selection after OU-1, 2 (3.4) …………………………………………………....285 0 С
Permissible steam temperature drop in controlled
production selection after OU-1.2 (3.4) ………………………………………………….…275 0 С
1.1.10. According to the thermal state of the turbine:
Maximum metal temperature rise rate
…..………………………………..15 0 S/min.
bypass pipes from AZV to HPC control valves
at temperatures of superheated steam below 450 degrees C.…………………………………….………25 0 С
Maximum allowable metal temperature difference
bypass pipes from AZV to HPC control valves
at a temperature of superheated steam above 450 degrees C.……………………………………….…….20 0 C
Maximum allowable temperature difference of the top metal
and bottom HPC (LPC) in the steam inlet zone ………………….…………………………………………..50 0 С
The maximum allowable temperature difference of the metal in
cross section(in width) horizontal flanges
cylinder connector without turning on the heating system
flanges and studs of the HPC.
HPC connector with the heating of flanges and studs on …………………………………..…50 0 С
in the cross section (in width) of the flanges of the horizontal
HPC connector with the heating of flanges and studs on ……………………………….……-25 0 С
The maximum allowable temperature difference of the metal between the upper
and lower (right and left) HPC flanges when
heating of flanges and studs ………………………………………………….…………………....10 0 С
Maximum allowable positive temperature difference of metal
between flanges and HPC studs with heating on
flanges and studs …………………………………………………………….…………………….20 0 С
Maximum allowable negative metal temperature difference
between flanges and HPC studs with the heating of flanges and studs on ………………………………………………………………………………………..…..- 20 0 С
The maximum allowable temperature difference of the metal in thickness
cylinder wall, measured in the area of the HPC control stage ….………………………….35 0 С
bearings and turbine thrust bearing …………………………………….……...…..90 0 C
Maximum allowable temperature support liners
generator bearings …………………………………………………….…………..………..80 0 C
1.1.11. According to the mechanical condition of the turbine:
Maximum permissible shortening of the high pressure hose relative to the high pressure head….……………………………….-2 mm
Maximum allowable elongation of the high pressure hose relative to the high pressure cylinder ….……………………………….+3 mm
Maximum allowable shortening of the RND relative to the LPC ….……………………..………-2.5 mm
Maximum allowable elongation of the RND relative to the LPC …….……………………..…….+3 mm
Maximum permissible distortion of the turbine rotor …………….…………………………..0.2 mm
Maximum allowable maximum value curvature
shaft of the turbine unit during the passage of critical speeds ………………………..0.25 mm
generator side ……………………………………………………….…………………..…1.2 mm
Maximum allowable axial shift of the turbine rotor in
side of the control unit …………………………………………….…………………….1.7 mm
1.1.12. According to the vibration state of the turbine unit:
The maximum allowable vibration velocity of the turbine unit bearings
in all modes (except for critical speeds) ……………….…………………….4.5 mm/s
with an increase in the vibration velocity of the bearings more than 4.5 mm/s
The maximum allowable duration of operation of the turbine unit
with an increase in the vibration velocity of bearings more than 7.1 mm / s ……….…………………… 7 days
Emergency increase in vibration velocity of any of the rotor supports ………….……………………11.2 mm/s
Emergency sudden simultaneous increase in the vibration velocity of two
single rotor supports, or adjacent supports, or two vibration components
one support from any initial value………………………………………………... by 1 mm or more
1.1.13. According to the flow rate, pressure and temperature of the circulating water:
Total consumption of cooling water for the turbine unit ………….………………………….8300 m 3 /hour
Maximum flow rate of cooling water through the condenser ….…………………………..8000 m 3 /hour
Minimum flow rate of cooling water through the condenser ……………….……………..2000 m 3 /hour
Maximum water flow through the built-in condenser bundle ……….………………1500 m 3 / hour
Minimum water flow through the built-in condenser bundle ………………………..300 m 3 / hour
Maximum temperature of the cooling water at the inlet to the condenser….……………………………………………………………………………………..33 0 С
The minimum temperature of the circulating water at the inlet to
condenser during sub-zero outdoor temperatures ………...……………….8 0 С
The minimum pressure of the circulating water at which the ATS of the circulation pumps TsN-1,2,3,4 operates…………………………………………………………..0.4 kgf/cm 2
Maximum pressure of circulating water in the pipe system
left and right halves of the condenser ………………………………………….……….……….2.5 kgf / cm 2
Maximum absolute water pressure in the pipe system
built-in condenser beam.………………………………………………………………….8 kgf / cm 2
Nominal hydraulic resistance of the condenser at
clean pipes and a flow rate of circulating water of 6500 m 3 / hour………………………..……...3.8 m. of water. Art.
Maximum temperature difference of the circulating water between
its entry into the capacitor and exit from it …………………………………………………..10 0 С
1.1.14. According to the flow rate, pressure and temperature of steam and chemically desalted water to the condenser:
Maximum consumption of chemically desalted water in the condenser ………………..……………..100 t/h.
Maximum steam flow to the condenser in all modes
operation …………………………………………………………………………….………220 t/h.
Minimum steam flow through the turbine LPC to the condenser
with closed rotary diaphragm …………………………………………………….……10 t/h.
The maximum allowable temperature of the exhaust part of the LPC ……………………….……..70 0 С
The maximum allowable temperature of chemically demineralized water,
entering the condenser …………………………………………………………….………100 0 С
The absolute vapor pressure in the exhaust part of the LPC at which
atmospheric valves-diaphragms work ………………………………………..……..1.2 kgf / cm 2
1.1.15. By absolute pressure (vacuum) in the turbine condenser:
Nominal absolute pressure in the condenser……………………………….………………0.035 kgf/cm 2
Permissible decrease in vacuum in the condenser at which a warning alarm is triggered………………. ………………………..………...-0.91 kgf/cm 2
Emergency reduction of vacuum in the condenser at which
The turbine unit is switched off by the protection………………………………………………………………....-0.75 kgf/cm 2
discharge of hot streams into it ….…………………………………………………………….….-0.55 kgf / cm 2
Permissible vacuum in the condenser when starting the turbine before
turbine unit shaft push …………………………………………………………………..……-0.75 kgf/cm 2
Permissible vacuum in the condenser when starting the turbine at the end
shutter speed of rotation of its rotor with a frequency of 1000 rpm …………….……………………..…….-0.95 kgf / cm 2
1.1.16. According to the steam pressure and temperature of the turbine seals:
Minimum absolute steam pressure at turbine seals
behind the pressure regulator ……………………………………………………………………………….1.1 kgf / cm 2
Maximum absolute steam pressure on turbine seals
behind the pressure regulator …………………………………………………………………………….1.2 kgf / cm 2
Minimum absolute steam pressure behind the turbine seals
to the pressure maintaining regulator …….……………………………………………………….….1.3kgf/cm2
Maximum absolute steam pressure behind turbine seals…
to the pressure maintenance regulator ……………………………………………………………..….1.5 kgf/cm 2
The minimum absolute vapor pressure in the second seal chambers ………………………………………………………………………1.03 kgf/cm2
Maximum absolute steam pressure in the second seal chambers ……………………..1.05 kgf/cm2
Nominal steam temperature for seals …………………………………………………….150 0 C
1.1.17. According to the pressure and temperature of the oil for lubricating the bearings of the turbine unit:
Rated excess oil pressure in the bearing lubrication system
turbines to oil cooler.……………………………………………………………………..……..3 kgf/cm 2
Rated overpressure of oil in the lubrication system
bearings at the level of the shaft axis of the turbine unit…………...………………………………………….1kgf/cm 2
at the level of the shaft axis of the turbine unit at which the
warning alarm …………………………………………………………..………..0.8 kgf/cm 2
Excessive oil pressure in the bearing lubrication system
at the level of the shaft axis of the turbine unit at which the RMN is turned on …………………………………….0.7 kgf / cm 2
Excessive oil pressure in the bearing lubrication system
at the level of the shaft axis of the turbine unit at which the AMN is switched on ……………………………..….0.6 kgf / cm 2
Excessive oil pressure in the bearing lubrication system at the level
shaft axis of the turbine unit at which the TLU is turned off by protection …… ………………………..…0.3 kgf/cm 2
Emergency excess oil pressure in the bearing lubrication system
at the level of the turbine shaft axis at which the turbine unit is switched off by the protection …………………………………………………………………………………….…………..0 .3 kgf / cm 2
Nominal oil temperature for lubrication of turbine unit bearings ………………………..40 0 С
Maximum allowable oil temperature for bearing lubrication
turbine unit ……………………………………………………………………………………….…45 0 С
The maximum allowable oil temperature at the drain from
turbine unit bearings …………………………………………………………………………....65 0 С
Emergency oil temperature at the drain from the bearings
turbine unit ………………………………………………………………………………….………75 0 C
1.1.18. By oil pressure in the turbine control system:
Excessive oil pressure in the turbine control system created by PMN……………………………………………………………………..……………..…18 kgf/cm 2
Excessive oil pressure in the turbine control system created by HMN……………………………………………………………………………..……..20 kgf/cm 2
Excessive oil pressure in the turbine control system
At which there is a ban on closing the valve on pressure and turning off the PMN .... ... ... ... .17.5 kgf / cm 2
1.1.19. By pressure, level, flow and temperature of oil in the turbogenerator shaft seal system:
Excessive oil pressure in the sealing system of the turbogenerator shaft in which the AVR is turned on to operation to work with the backup of the alternating current ........................................................................ 8 kgf / cm 2
Excessive oil pressure in the turbogenerator shaft sealing system at which the AVR is put into operation
backup MNUV DC…………………………………………………………………..7 kgf/cm 2
Permissible minimum difference between the oil pressure on the shaft seals and the hydrogen pressure in the turbogenerator housing……………………………..0.4 kgf/cm2
Permissible maximum difference between the oil pressure on the shaft seals and the hydrogen pressure in the turbogenerator housing…………………….….....0.8 kgf/cm2
Maximum difference between inlet oil pressure and pressure
oil at the outlet of the MFG at which it is necessary to switch to the reserve oil filter generator…………………………………………………………………………….1kgf/cm 2
Nominal oil temperature at the outlet from MOG………………………………………………..40 0 С
Permissible increase in oil temperature at the outlet from MOG……………………….…….…….45 0 С
1.1.20. According to the temperature and flow rate of feed water through the HPH group of the turbine:
Nominal feed water temperature at the inlet to the HPH group ….……………………….164 0 С
The maximum temperature of the feed water at the outlet of the HPH group at the rated power of the turbine unit……………………………………………………………..…249 0 С
Maximum feed water flow through the HPH pipe system …………………...…...550 t/h
1.2.Turbine technical data.
| Turbine rated power | 80 MW |
| The maximum power of the turbine with fully switched on regeneration for certain combinations of production and heat extraction, determined by the mode diagram | 100 MW |
| Absolute live steam pressure by automatic shut-off valve | 130 kgf/cm² |
| Steam temperature before stop valve | 555 °С |
| Absolute pressure in the condenser | 0.035 kgf/cm² |
| Maximum steam flow through the turbine when operating with all extractions and with any combination of them | 470 t/h |
| Maximum steam flow to the condenser | 220 t/h |
| Cooling water flow to the condenser at a design temperature at the condenser inlet of 20 °С | 8000 m³/h |
| Absolute vapor pressure of controlled production extraction | 13±3 kgf/cm² |
| Absolute steam pressure of controlled top heat extraction | 0.5 - 2.5 kgf / cm² |
| Absolute steam pressure of controlled lower heating extraction with a single-stage scheme for heating network water | 0.3 - 1 kgf / cm² |
| Feed water temperature after HPH | 249 °С |
| Specific consumption couple (guaranteed POT LMZ) | 5.6 kg/kWh |
Note: The start-up of a turbine set stopped due to an increase (change) in vibration is allowed only after a detailed analysis of the causes of vibration and with the permission of the chief engineer of the power plant, made by him personally in the operational log of the station shift supervisor.
1.6 The turbine must be stopped immediately in the following cases:
· Increasing the speed above 3360 rpm.
· Detection of a rupture or a through crack in non-switchable sections of oil pipelines, steam and water paths, and steam distribution units.
· Occurrence of hydraulic shocks in live steam pipelines or in the turbine.
· Emergency reduction of vacuum to -0.75 kgf/cm² or actuation of atmospheric valves.
A sharp decrease in the temperature of fresh water
The first ten disks of the low-pressure rotor are forged integrally with the shaft, the remaining three disks are mounted.
The HP and LPC rotors are connected rigidly with the help of flanges forged integrally with the rotors. The rotors of the LPC and the TVF-120-2 type generator are connected by a rigid coupling.
The steam distribution of the turbine is nozzle. Fresh steam is supplied to a free-standing nozzle box, in which an automatic shutter is located, from where the steam enters the turbine control valves through bypass pipes.
Upon leaving the HPC, part of the steam goes to controlled production extraction, the rest goes to the LPC.
Heating extractions are carried out from the corresponding LPC chambers.
The turbine fixing point is located on the turbine frame on the generator side, and the unit expands towards the front bearing.
To reduce the warm-up time and improve start-up conditions, steam heating of flanges and studs and live steam supply to the HPC front seal are provided.
The turbine is equipped with a barring device that rotates the shafting of the unit with a frequency of 0.0067.
The blade apparatus of the turbine is designed and configured to operate at a mains frequency of 50 Hz, which corresponds to the rotation of the rotor 50. Continuous operation of the turbine is allowed at a mains frequency of 49 to 50.5 Hz.
The height of the foundation of the turbine unit from the floor level of the condensation room to the floor level of the engine room is 8 m.
2.1 Description of the principle thermal diagram of the turbine PT–80/100–130/13
The condensing device includes a condensing group, an air-removing device, condensate and circulation pumps, ejector circulation system, water filters, pipelines with the necessary fittings.
The condenser group consists of one condenser with a built-in bundle with a total cooling surface of 3000 m² and is designed to condense the steam entering it, creating a vacuum in the turbine exhaust pipe and storing condensate, as well as to use the heat of the steam entering the condenser in operating modes according to the heat schedule for heating make-up water in the built-in bundle.
The condenser has a special chamber built into the steam part, in which the HDPE section No. 1 is installed. The rest of the PND are installed by a separate group.
The regenerative plant is designed to heat feed water with steam taken from unregulated turbine extractions, and has four stages of HDPE, three stages of HPH and a deaerator. All heaters are surface type.
HPH No. 5,6 and 7 - vertical design with built-in desuperheaters and drain coolers. HPH are supplied with group protection, consisting of automatic exhaust and check valves at the inlet and outlet of water, an automatic valve with an electromagnet, a pipeline for starting and switching off heaters.
HPH and HDPE (except HDPE No. 1) are equipped with control valves for condensate removal, controlled by electronic regulators.
The heating steam condensate drain from the heaters is cascaded. Condensate is pumped out from HDPE No. 2 by a drain pump.
The installation for heating network water includes two network heaters, condensate and network pumps. Each heater is a horizontal steam-to-water heat exchanger with a heat exchange surface of 1300 m², which is formed by straight brass pipes, flared on both sides in tube sheets.
3 Selection of auxiliary equipment of the station thermal scheme
3.1 Equipment supplied with the turbine
Because condenser, main ejector, low and high pressure heaters are supplied to the designed station together with the turbine, then the following are used for installation at the station:
a) Condenser type 80-KTsST-1 in the amount of three pieces, one for each turbine;
b) The main ejector type EP-3-700-1 in the amount of six pieces, two for each turbine;
c) Low-pressure heaters of the type PN-130-16-10-II (PND No. 2) and PN-200-16-4-I (PND No. 3,4);
d) High-pressure heaters of the type PV-450-230-25 (PVD No. 1), PV-450-230-35 (PVD No. 2) and PV-450-230-50 (PVD No. 3).
The characteristics of the above equipment are summarized in tables 2, 3, 4, 5.
Table 2 - capacitor characteristics
Table 3 - characteristics of the main condenser ejector
Comprehensive modernization of the steam turbine PT-80/100-130/13
The purpose of the modernization is to increase the electrical and heating power of the turbine with an increase in the efficiency of the turbine plant. Modernization in the scope of the main option consists in the installation of honeycomb shroud seals of the HPC and the replacement of the medium pressure flow path with the manufacture of a new LP rotor in order to increase bandwidth NPV up to 383 t/h. At the same time, the range of pressure regulation in the production extraction is maintained, the maximum steam flow to the condenser does not change.
Replaceable units when upgrading the turbine unit in the scope of the basic option:
- Installation of honeycomb shroud seals 1-17 HPC stages;
- Guide apparatus TsSND;
- Saddles of the RC ChSD with a larger flow area with the completion of the steam boxes of the upper half of the ChSD body for the installation of new covers;
- SD control valves and cam-distributing device;
- Diaphragms of 19-27 stages of TsSND, equipped with over-shroud honeycomb seals and sealing rings with twisted springs;
- SND rotor with installed new working blades of 18-27 stages of TsSND with integrally milled bandages;
- Diaphragm holders No. 1, 2, 3;
- Carrier of front end seals and O-rings with twisted springs;
- The 28, 29, 30 stage top discs are retained in accordance with the existing design, which reduces the cost of retrofitting (provided that the old top discs are used).
As a result of modernization according to the main option, the following is achieved:
- Increasing the maximum electric power of the turbine up to 110 MW and the power of heat extraction up to 168.1 Gcal/h due to the reduction of industrial extraction.
- Ensuring reliable and maneuverable operation of the turbine plant in all operating modes, including at the lowest possible pressures in industrial and heat extraction.
- Increasing the efficiency of the turbine plant;
- Ensuring the stability of the achieved technical and economic indicators during the overhaul period.
The effect of modernization in the scope of the main offer:
| Turbine unit modes | Electric power, MW | Steam consumption for heating, t/h | Steam consumption for production, t/h |
Condensing | |||
Nominal | |||
Max power | |||
With maximum | |||
Increasing the efficiency of the CHSD | |||
Increasing the efficiency of the HPC | |||
Additional offers (options) for modernization
- Modernization of the casing of the HPC control stage with the installation of over-shroud honeycomb seals
- Installing diaphragms of the last stages with a tangential bulk
- Highly hermetic seals for HPC control valve stems
The effect of modernization by additional options
№ | Name | the effect |
Modernization of the casing of the HPC control stage with the installation of over-shroud honeycomb seals | Power increase by 0.21-0.24 MW |
|
Installing diaphragms of the last stages with a tangential bulk | Condensing mode: |
|
Rotary diaphragm seal | Increasing the efficiency of the turbine plant when operating in the mode with a fully closed rotary diaphragm 7 Gcal/h |
|
Replacement of shroud seals of HPC and HPC with honeycomb ones | Increasing the efficiency of cylinders (high pressure cylinder by 1.2-1.4%, TsSND by 1%); |
|
Replacement of HPC control valves | Power increase by 0.02-0.11 MW |
|
Installation of LPC honeycomb end seals | Elimination of air suction through the end seals |
