Steam distribution table fri 80 100 13 130. For the operation of the steam turbine. Thermal balance of the POV chemically purified water heater

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In this term paper the calculation of the basic thermal scheme of the power plant based on the cogeneration steam turbine

PT-80/100-130/13 at temperature environment, the system of regenerative heating and network heaters, as well as the indicators of thermal efficiency of the turbine plant and power unit are calculated.

The appendix shows a schematic thermal diagram based on the PT-80/100-130/13 turbine plant, a graph of temperatures of network water and heating load, h-s diagram of steam expansion in the turbine, a diagram of modes of the PT-80/100-130/13 turbine plant, a general view of the heater high pressure PV-350-230-50, specification general view PV-350-230-50, longitudinal section of turbine plant PT-80/100-130/13, general view specification auxiliary equipment included in the TPP scheme.

The work is composed on 45 sheets and includes 6 tables and 17 illustrations. 5 literary sources were used in the work.

Introduction
Review of scientific and technical literature (Technologies for the generation of electrical and thermal energy)
1. Description of the principal thermal diagram of the PT-80/100-130/13 turbine plant
2. Calculation of the principal thermal diagram of the PT-80/100-130/13 turbine plant in the increased load mode

2.1 Initial data for calculation
2.2
2.3 Calculation of the parameters of the steam expansion process in the turbine compartments inh- Sdiagram
2.4
2.5
2.6

2.6.1 Network heating installation (boiler)
2.6.2 High pressure regenerative heaters and feed plant (pump)
2.6.3 Deaerator feed water
2.6.4 Raw water heater
2.6.5
2.6.6 Additional water deaerator
2.6.7
2.6.8 Capacitor

2.7
2.8 Energy balance of the turbine unit PT-80/100-130/13
2.9
2.10

Conclusion
Bibliography
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.
1. Description of the principal thermal diagram of the turbine plant PT-80/100-130/13

The 80 MW electric power unit consists of an E-320/140 high-pressure drum boiler, a PT-80/100-130/13 turbine, a 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 It enters the turbine HPC and, after exhausting, is sent to the turbine HPC, and then to the HPC. 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 unit 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, the scheme provides for the intake of 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 ensure heating and deaeration of 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

2. Calculation of the principle thermal diagram of a turbine plantFri-80/100-130/13 in high load mode

Calculation of the basic thermal scheme of the turbine plant is based on the given steam flow rate for the turbine. As a result of the calculation, determine:

? electrical power of the turbine unit - W e;

? energy performance of the turbine plant and CHP as a whole:

b. efficiency factor of CHPP for electricity generation;

in. efficiency factor of CHPP for the production and supply of heat for heating;

d. specific consumption of reference fuel for electricity generation;

e. Specific consumption of reference fuel for the production and supply of thermal energy.

2.1 Initial data for calculation

Live steam pressure -

Fresh steam temperature -

Pressure in the condenser - P to = 0.00226 MPa

Parameters of steam production selection:

steam consumption -

giving - ,

reverse - .

Fresh steam consumption for the turbine -

The efficiency values of the thermal circuit elements are given in Table 2.1.

Table 2.1. Efficiency factor of thermal circuit elements

Thermal circuit element	Efficiency
	Designation	Meaning
Continuous Purge Expander
Lower network heater
Upper network heater
Regenerative heating system:







Feed pump
Feed water deaerator
Purge cooler
Purified water heater
Condensate water deaerator
Faucets
Seal heater
Seal ejector
Pipelines
Generator

2.2 Calculation of pressures in turbine extractions

The heat load of the CHPP is determined by the needs of the production consumer of steam and the supply of heat to an external consumer for heating, ventilation and hot water supply.

To calculate the characteristics of the thermal efficiency of a CHP plant with an industrial heat and power turbine in an increased load mode (below -5ºС), it is necessary to determine the steam pressure in the turbine bleeds. This pressure is set based on the requirements of the industrial consumer and the temperature schedule of the network water.

In this course work, a constant steam extraction for the technological (industrial) needs of an external consumer is adopted, which is equal to the pressure, which corresponds to the nominal operation of the turbine plant, therefore, the pressure in the unregulated turbine extractions No. 1 and No. 2 is:

The steam parameters in the turbine extractions at nominal mode are known from its main technical characteristics.

It is necessary to determine the actual (i.e. for a given mode) pressure value in the heat extraction. To do this, the following sequence of actions is performed:

1. According to the given value and the selected (given) temperature graph of the heating network, we determine the temperature of the network water behind the network heaters at a given outdoor temperature t NAR

t Sun = t O.S + b CHP ( t P.S - t O.S)

t BC \u003d 55.6 + 0.6 (106.5 - 55.6) \u003d 86.14 0 C

2. According to the accepted value of water undercooling and and value t BC we find the saturation temperature in the network heater:

= t sun + and

86.14 + 4.3 \u003d 90.44 0 С

Then, according to the saturation tables for water and steam, we determine the steam pressure in the network heater R BC = 0.07136 MPa.

3. The heat load on the lower network heater reaches 60% of the total load on the boiler room

t NS = t O.S + 0.6 ( t V.S - t O.S)

t NS \u003d 55.6 + 0.6 (86.14 - 55.6) \u003d 73.924 0 C

According to the saturation tables for water and steam, we determine the steam pressure in the network heater R H C \u003d 0.04411 MPa.

4. We determine the steam pressure in the cogeneration (regulated) extractions No. 6, No. 7 of the turbine, taking into account the accepted pressure losses through pipelines:

where losses in pipelines and control systems of the turbine are accepted:; ;

5. According to the steam pressure value ( R 6 ) in the heating extraction No. 6 of the turbine, we specify the steam pressure in the unregulated turbine extractions between the industrial extraction No. 3 and the controlled heating extraction No. 6 (according to the Flugel-Stodola equation):

where D 0 , D, R 60 , R 6 - steam flow rate and pressure in the turbine extraction in the nominal and calculated mode, respectively.

2.3 Calculation of parameterssteam expansion process in the turbine compartments inh- Sdiagram

Using the method described below and the values of pressures in the extractions found in the previous paragraph, we construct a diagram of the process of steam expansion in the turbine flow path at t bunk=- 15 є FROM.

Intersection point on h, s- isobar diagram with isotherm determines the enthalpy of fresh steam (point 0 ).

The loss of live steam pressure in the stop and control valves and the start-up vapor path with valves fully open is approximately 3%. Therefore, the steam pressure in front of the first stage of the turbine is:

On the h, s- the diagram shows the point of intersection of the isobar with the level of enthalpy of fresh steam (point 0 /).

To calculate the steam parameters at the outlet of each turbine compartment, we have the values of the internal relative efficiency of the compartments.

Table 2.2. Internal relative efficiency of the turbine by compartments

From the obtained point (point 0 /) a line is drawn vertically downward (along the isentrope) to the intersection with the pressure isobar in selection No. 3. The enthalpy of the intersection point is equal to.

The enthalpy of steam in the chamber of the third regenerative selection in the real expansion process is equal to:

Similar to h,s- the diagram contains points corresponding to the state of steam in the chamber of the sixth and seventh selections.

After constructing the steam expansion process in h, S- the diagram shows isobars of unregulated extractions for regenerative heaters R 1 , R 2 ,R 4 ,R 5 and the enthalpies of steam in these extractions are established.

built on h,s- in the diagram, the points are connected by a line, which reflects the process of steam expansion in the flow path of the turbine. The graph of the steam expansion process is shown in Figure A.1. (Appendix A).

According to the built h,s- the diagram determines the temperature of the steam in the corresponding selection of the turbine by the values of its pressure and enthalpy. All parameters are given in table 2.3.

2.4 Calculation of thermodynamic parameters in heaters

The pressure in regenerative heaters is less than the pressure in the extraction chambers by the amount of pressure loss due to the hydraulic resistance of the extraction pipelines, safety and stop valves.

1. We calculate the pressure of saturated water vapor in regenerative heaters. The pressure losses in the pipeline from the turbine extraction to the corresponding heater are taken equal to:

The pressure of saturated water vapor in the feed and condensate water deaerators is known from their technical characteristics and is equal to, respectively,

2. According to the table of properties of water and steam in the state of saturation, according to the saturation pressures found, we determine the temperatures and enthalpies of the heating steam condensate.

3. We accept undercooling of water:

In high pressure regenerative heaters - 2єFROM

In low pressure regenerative heaters - 5єFROM,

In deaerators - 0є FROM ,

therefore, the water temperature at the outlet of these heaters is:

, є FROM

4. The water pressure behind the respective heaters is determined by the hydraulic resistance of the tract and the operating mode of the pumps. The values of these pressures are accepted and are given in Table 2.3.

5. According to the tables for water and superheated steam, we determine the enthalpy of water after the heaters (by the values and):

6. Water heating in the heater is defined as the difference between the enthalpies of water at the inlet and outlet of the heater:

, kJ/kg;

kJ/kg;

kJ/kg

kJ/kg;

kJ/kg,

where is the enthalpy of the condensate at the outlet of the seal heater. In this work, this value is taken equal to.

7. The heat given off by the heating steam to the water in the heater:

2.5 Steam and water parameters in the turbine plant

For the convenience of further calculation, the parameters of steam and water in the turbine plant, calculated above, are summarized in Table 2.3.

Data on steam and water parameters in drain coolers are given in Table 2.4.

Table 2.3. Steam and water parameters in the turbine plant

p, MPa

t, 0 FROM

h, kJ/kg

p", MPa

t" H, 0 FROM

h B H, kJ/kg

0 FROM

p B, MPa

t P, 0 FROM

h B P, kJ/kg

kJ/kg

Table 2.4. Steam and water parameters in drain coolers

2.6 Determination of steam and condensate flow rates in the elements of the thermal scheme

The calculation is performed in the following order:

1. Steam flow to the turbine in the design mode.

2. Steam leaks through seals

Accept, then

4. Feed water consumption per boiler (including blowdown)

where is the amount of boiler water going into the continuous blowdown

D etc=(b etc/100)·D pg=(1.5/100) 131.15=1.968kg/s

5. Steam outlet from purge expander

where is the proportion of steam released from the blowdown water in the continuous blowdown expander

6.Blowdown water outlet from expander

7. Consumption of additional water from the chemical water treatment plant (CWT)

where is the condensate return coefficient from

production consumers, we accept;

Calculation of steam flow rates in regenerative and network heaters in the deaerator and condenser, as well as condensate flow rates through heaters and mixers is based on the equations of material and heat balances.

Balance equations are compiled sequentially for each element of the thermal scheme.

The first stage in the calculation of the thermal scheme of a turbine plant is the preparation of heat balances for network heaters and the determination of steam flow rates for each of them based on the given thermal load of the turbine and the temperature graph. After that, heat balances of high pressure regenerative heaters, deaerators and low pressure heaters are compiled.

2.6.1 Network heating installation (boiler room)

Table 2.5. Steam and water parameters in a network heating plant

Index	Bottom heater	Top heater
Heating steam Selection pressure P, MPa
Pressure in the heater Р?, MPa
Steam temperature t, ºС
Heat output qns, qvs, kJ/kg
Heating steam condensate Saturation temperature tn, єС
Enthalpy at saturation h?, kJ/kg
Network water Underheating in the heater Ins, Ivs, єС
Inlet temperature tс, tns, єС
Inlet enthalpy, kJ/kg
Outlet temperature tns, tvs, єС
Output enthalpy, kJ/kg
Heating in the heater fns, fvs, kJ/kg

The installation parameters are defined in the following sequence.

1. Consumption of network water for the calculated mode

2.Heat balance of the lower network heater

Heating steam flow to the lower network heater

from Table 2.1.

3.Heat balance of the upper network heater

Heating steam flow to the upper network heater

Regenerative high temperature heaters pressure and feed plant (pump)

LDPE 7

HPH7 heat balance equation

Heating steam consumption for PVD7

LDPE 6

Heat balance equation for HPH6

Heating steam consumption for PVD6

heat removed from the drainage OD2

Feed pump (PN)

Pressure after PN

Pressure in the pump in PN

Pressure drop

The specific volume of water in PN v PN - determined from the tables by value

R Mon.

Feed pump efficiency

Water heating in Mon

Enthalpy after PN

Where - from table 2.3;

HPH5 heat balance equation

Heating steam consumption for PVD5

2.6.3 Feed water deaerator

The steam flow rate from the seals of the valve stems in the DPV is accepted

Steam enthalpy from valve stem seals

(at P = 12,9 MPa and t=556 0 FROM) :

Evaporation from the deaerator:

D issue=0,02 D PV=0.02

The share of steam (in fractions of the vapor from the deaerator going to the PE, the seals of the middle and end seal chambers

Deaerator material balance equation:

.

Deaerator heat balance equation

After substituting into this equation the expression D CD we get:

Heating steam consumption from the third turbine extraction to the DPV

hence the consumption of heating steam from the turbine extraction No. 3 to the DPV:

D D = 4.529.

Condensate flow at the deaerator inlet:

D KD \u003d 111.82 - 4.529 \u003d 107.288.

2.6.4 Raw water heater

Drainage enthalpy h PSV=140

.

2.6.5 Two Stage Purge Expander

2nd stage: expansion of water boiling at 6 atm in quantity

up to a pressure of 1 atm.

= + (-)

sent to the atmospheric deaerator.

2.6.6 Additional water deaerator

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Equation of the material balance of the return condensate deaerator and additional water DKV.

D KV = + D P.O.V + D OK + D OV;

Consumption of chemically treated water:

D OB = ( D P - D OK) + + D UT.

Thermal balance of the blowdown water cooler

material turbine condensate

where q OP = h h heat supplied to the additional water in the OP.

q OP \u003d 670.5- 160 \u003d 510.5 kJ / kg,

where: h enthalpy of blowdown water at the outlet of the OP.

We accept the return of condensate from industrial heat consumers?k = 0.5 (50%), then:

D OK = ?k* D P = 0.5 51.89 = 25.694 kg / s;

D RH = (51.89 - 25.694) + 1.145 + 0.65 = 27.493 kg/s.

The additional water heating in the OP is determined from the OP heat balance equation:

= 27.493 from here:

= 21.162 kJ/kg.

After the blowdown cooler (BP), the additional water enters the chemical water treatment, and then to the chemically treated water heater.

Thermal balance of the POV chemically purified water heater:

where q 6 - the amount of heat transferred in the heater by steam from turbine extraction No. 6;

water heating in POV. Accept h RH = 140 kJ/kg, then

.

The steam flow rate for SOW is determined from the heat balance of the chemically treated water heater:

D POV 2175.34 = 27.493 230.4 from where D POV = 2.897 kg / s.

In this way,

D KV = D

Heat balance equation for chemically treated water deaerator:

D h 6 + D POV h+ D OK h+ D OV hD HF h

D 2566,944+ 2,897 391,6+ 25,694 376,77 + 27,493 370,4= (D+ 56,084) * 391,6

From here D\u003d 0.761 kg / s - heating steam consumption at the DKV and extraction No. 6 of the turbine.

The flow of condensate at the outlet of the DKV:

D KV \u003d 0.761 + 56.084 \u003d 56.846 kg / s.

2.6.7 Low pressure regenerative heaters

HDPE 4

Heat balance equation for HDPE4

.

Heating steam consumption for LPH4

,

where

HDPE and mixerCM2

Combined heat balance equation:

where is the condensate flow at the LPH2 outlet:

D K6 = D KD - D HF -D Sun - D PSV = 107,288 -56,846 - 8,937 - 2,897 = 38,609

substitute D K2 into the combined heat balance equation:

D\u003d 0.544 kg / s - heating steam consumption at LPH3 from selection No. 5

turbines.

PND2, mixer CM1, PND1

Temperature for PS:

1 material equation and 2 heat balance equations are compiled:

1.

2.

3. substitute into equation 2

We get:

kg/s;

D P6 = 1,253 kg/s;

D P7 = 2,758 kg/s.

2.6.8 Capacitor

Capacitor Material Balance Equation

.

2.7 Checking the material balance calculation

Checking the correctness of taking into account in the calculations of all flows of the thermal scheme is carried out by comparing the material balances for steam and condensate in the turbine condenser.

Exhaust steam flow to condenser:

,

where is the steam flow rate from the turbine extraction chamber with the number.

Steam flow rates from extractions are given in Table 2.6.

Table 2.6. Steam consumption for turbine extractions

Selection No.	Designation	Steam consumption, kg/s
	D 1 =D P1
	D 2 =D P2
	D 3 =D P3+D D+D P
	D 4 =D P4
	D 5 = D NS + D P5
	D 6 =D P6+D sun++D PSV
	D 7 =D P7+D HC

Total steam flow from turbine extractions

Steam flow to the condenser after the turbine:

Steam and condensate balance error

Since the error in the balance of steam and condensate does not exceed the permissible value, therefore, all flows of the thermal scheme are taken into account correctly.

2.8 Energy balance of the turbine unit Fri- 80/100-130/13

Let us determine the power of the turbine compartments and its total power:

N i=

where N i OTS - power of the turbine compartment, N i UTS = D i UTS H i UTS,

H i UTS = H i UTS - H i +1 HTS - heat drop in the compartment, kJ/kg,

D i OTS - passage of steam through the compartment, kg/s.

compartment 0-1:

D 01 UTS = D 0 = 130,5 kg/s,

H 01 UTS = H 0 UTS - H 1 UTS = 34 8 7 - 3233,4 = 253,6 kJ/kg,

N 01 UTS = 130,5 . 253,6 = 33,095 MVt.

- compartment 1-2:

D 12 UTS = D 01 -D 1 = 130,5 - 8,631 = 121,869 kg/s,

H 12 UTS = H 1 UTS - H 2 UTS = 3233,4 - 3118,2 = 11 5,2 kJ/kg,

N 12 UTS = 121,869 . 11 5,2 = 14,039 MVt.

- compartment 2-3:

D 23 UTS =D 12 -D 2 = 121,869 - 8,929 = 112,94 kg/s,

H 23 UTS = H 2 UTS - H 3 UTS = 3118,2 - 2981,4 = 136,8 kJ/kg,

N 23 UTS = 112,94 . 136,8 = 15,45 MVt.

- compartment 3-4:

D 34 UTS = D 23 -D 3 = 112,94 - 61,166 = 51,774 kg/s,

H 34 UTS = H 3 UTS - H 4 UTS = 2981,4 - 2790,384 = 191,016 kJ/kg,

N 34 UTS = 51,774 . 191,016 = 9,889 MVt.

- compartment 4-5:

D 45 UTS = D 34 -D 4 = 51,774 - 8,358 = 43,416 kg/s,

H 45 UTS = H 4 UTS - H 5 UTS = 2790,384 - 2608,104 = 182,28 kJ/kg,

N 45 UTS = 43,416 . 182,28 = 7,913 MVt.

- compartment 5-6:

D 56 UTS = D 45 -D 5 = 43,416 - 9,481 = 33, 935 kg/s,

H 56 UTS = H 5 UTS - H 6 UTS = 2608,104 - 2566,944 = 41,16 kJ/kg,

N 45 UTS = 33, 935 . 41,16 = 1,397 MVt.

- compartment 6-7:

D 67 UTS = D 56 -D 6 = 33, 935 - 13,848 = 20,087 kg/s,

H 67 UTS = H 6 UTS - H 7 UTS = 2566,944 - 2502,392 = 64,552 kJ/kg,

N 67 UTS = 20,087 . 66,525 = 1, 297 MVt.

- compartment 7-K:

D 7k UTS = D 67 -D 7 = 20,087 - 13,699 = 6,388 kg/s,

H 7k UTS = H 7 UTS - H to UTS = 2502,392 - 2442,933 = 59,459 kJ/kg,

N 7k UTS = 6,388 . 59,459 = 0,38 MVt.

3.5.1 Total power of turbine compartments

3.5.2 The electrical power of the turbine set is determined by the formula:

N E = N i

where is the mechanical and electrical efficiency of the generator,

N E \u003d 83.46. 0.99. 0.98=80.97MW.

2.9 Turbine thermal efficiency indicators

Total heat consumption for the turbine plant

, MW

.

2. Heat consumption for heating

,

where h T- coefficient taking into account heat losses in the heating system.

3. Total heat consumption for industrial consumers

,

.

4. Total heat consumption for external consumers

, MW

.

5. Heat consumption for the turbine plant for the production of electricity

,

6. Efficiency of the turbine plant for the production of electricity (excluding own consumption of electricity)

,

.

7. Specific heat consumption for electricity generation

,

2.10 Energy indicators of CHP

Fresh steam parameters at the outlet of the steam generator.

- pressure P PG = 12.9 MPa;

- Gross steam generator efficiency from SG = 0.92;

- temperature t SG = 556 о С;

- h PG = 3488 kJ / kg at the specified R PG and t PG.

Efficiency of the steam generator, taken from the characteristics of the boiler E-320/140

.

1. Thermal load of the steam generator set

, MW

2. Efficiency of pipelines (heat transport)

,

.

3. Efficiency of CHP for the production of electricity

,

.

4. Efficiency of the CHPP for the production and supply of heat for heating, taking into account the PVK

,

.

PVC at t H=- 15 0 FROM works,

5. Specific consumption of reference fuel for electricity generation

,

.

6. Specific consumption of reference fuel for the production and supply of thermal energy

,

.

7. Fuel heat consumption per station

,

.

8. Total efficiency of the power unit (gross)

,

9. Specific heat consumption per CHP power unit

,

.

10. Efficiency of the power unit (net)

,

.

where E S.N - own specific consumption of electricity, E S.N = 0.03.

11. Specific consumption of reference fuel "net"

,

.

12. Reference fuel consumption

kg/s

13. Consumption of reference fuel for the generation of heat supplied to external consumers

kg/s

14. Reference fuel consumption for electricity generation

V E U \u003d V U -V T U \u003d 13.214-8.757 \u003d 4.457 kg / s

Conclusion

As a result of 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 increased load mode at ambient temperature, the following values of the main parameters characterizing the power plant of this type were obtained:

Steam consumption in turbine extractions

Heating steam consumption for network heaters

Heat output for heating by a turbine plant

Q T= 72.22MW;

Heat output from a turbine plant to industrial consumers

Q P= 141.36 MW;

Total heat consumption for external consumers

Q TP= 231.58 MW;

Power at generator terminals

N uh=80.97 MW;

CHP efficiency for electricity generation

Efficiency of CHPP for the production and supply of heat for heating

Specific fuel consumption for electricity generation

b E At= 162.27g/kw/h

Specific fuel consumption for the production and supply of thermal energy

b T At= 40.427 kg/GJ

Gross total CHP efficiency

Total efficiency of CHP "net"

Specific reference fuel consumption per station "net"

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7. . Turbines of Thermal and Nuclear Power Plants: Textbook for High Schools / Ed. A.G., Kostyuk, V.V. Frolova. - 2nd ed., revised. and additional - M.: Izd MPEI, 2001. - 488 p.

8. Calculation of thermal circuits of steam turbine plants: Educational electronic edition / Poleshchuk I.Z. - GOU VPO UGATU, 2005.

Conventions power plants, equipment and their elements (includingtext, figures, indexes)

D - feed water deaerator;

DN - drainage pump;

K - condenser, boiler;

KN - condensate pump;

OE - drainage cooler;

PrTS - basic thermal diagram;

PVD, HDPE - regenerative heater (high, low pressure);

PVK - peak hot water boiler;

SG - steam generator;

PE - superheater (primary);

PN - feed pump;

PS - stuffing box heater;

PSG - horizontal network heater;

PSV - raw water heater;

PT - steam turbine; heating turbine with industrial and heating steam extraction;

PHOV - chemically purified water heater;

PE - ejector cooler;

P - expander;

CHPP - combined heat and power plant;

CM - mixer;

СХ - stuffing box cooler;

HPC - high pressure cylinder;

LPC - low pressure cylinder;

EG - electric generator;

Annex A

Annex B

Mode diagram PT-80/100

Annex B

Heating schedules for quality regulation of the releaseheat according to the average daily outdoor temperature

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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 an E-320/140 high-pressure drum boiler, a PT-80/100-130/13 turbine, a generator and auxiliary equipment.

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 main condensate and feed water are heated sequentially in PE, SH and PS, in four low-pressure heaters (LPH), in a 0.6 MPa deaerator and in three high-pressure heaters (HPV). Steam is supplied to these heaters from three adjustable and four unregulated turbine steam extractions.

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.

To make up for losses, the scheme provides for the intake of raw water. Raw water is heated in the raw water heater (RWS) to a temperature of 35 o C, then, after chemical treatment, it enters the deaerator 1.2 ata. To ensure heating and deaeration of 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.

Figure 1. Schematic diagram of a thermal power plant based on TU PT-80/100-130/13

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. Engineer of the TsTSCHU with steam turbines of the 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 of the branch of OAO "Kamchatskenergo" KTETs

Bolotenyuk Yu.N.

“ “ 20 y.

I N S T R U K T I A

Steam turbine operation manual

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. Lengthwise cut turbines……………………………………………………………..….…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 production 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

Limit deviation 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 С

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

The maximum allowable temperature of bearing shells

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

The maximum allowable maximum value of 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. By vibrational state 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 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

capacitor in period sub-zero temperatures outdoor air ………...……………….8 0 C

The minimum pressure of the circulating water at which the AVR operates circulation pumps TsN-1,2,3,4…………………………………………………………..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

Overpressure oils 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 turbogenerator shaft seal system in which a reserve volume of alternating current is included in the ABR .........................................................................................................................................................................................

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 of the 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 bottom heat extraction at single-stage scheme network water heating	0.3 - 1 kgf / cm²
Feed water temperature after HPH	249 °С
Specific steam consumption (guaranteed by 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 break or through crack on unswitched sections of oil pipelines, steam-water path, 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