T 50 130 cooling and heating turbine. Thermal diagram of a turbine unit

Turbine T -100/120-130

Single-shaft steam turbine T 100/120-130 with a rated power of 100 MW at 3000 rpm. With condensation and two heating extractions, the steam is designed to directly drive an alternating current generator, type TVF-100-2 with a power of 100 MW and hydrogen cooling.

The turbine is designed to operate with fresh steam parameters of 130 atm and a temperature of 565C, measured before the stop valve.

The nominal temperature of the cooling water at the condenser inlet is 20C.

The turbine has two heating outlets: upper and lower, designed for stepwise heating of network water in boilers.

The turbine can take a load of up to 120 MW at certain values ​​of heating steam extraction.

Turbine PT -65/75-130/13

Condensing turbine with controlled steam extraction for production and district heating without reheating, two-cylinder, single-flow, 65 MW.

The turbine is designed to operate with the following parameters pair:

Pressure in front of the turbine 130 kgf/cm 2,

Steam temperature in front of the turbine is 555 °C,

Steam pressure in production extraction is 10-18 kgf/cm 2,

Steam pressure in district heating extraction is 0.6-1.5 kgf/cm2,

Nominal pressure steam in the condenser 0.04 kgf/cm 2.

The maximum steam consumption per turbine is 400 t/h, the maximum steam extraction for production is 250 t/h, maximum amount released heat from hot water- 90 Gcal/h.

The regenerative turbine installation consists of four heaters low pressure, deaerator 6 kgf/cm 2 and three heaters high pressure. Part of the cooling water after the condenser is taken to the water treatment plant.

Turbine T-50-130

The T-50-130 single-shaft steam turbine with a rated power of 50 MW at 3000 rpm with condensation and two heating steam extractions is designed to drive an alternating current generator, type TVF 60-2, with a power of 50 MW and hydrogen cooling. A turbine that is put into operation is controlled from the monitoring and control panel.

The turbine is designed to operate with fresh steam parameters of 130 ata, 565 C 0, measured before the stop valve. The nominal temperature of the cooling water at the condenser inlet is 20 C 0.

The turbine has two heating outlets, upper and lower, designed for stepwise heating of network water in boilers. Heating of the feed water is carried out sequentially in the refrigerators of the main ejector and the ejector for suctioning steam from the seals with a stuffing box heater, four HDPE and three HDPE. HDPE No. 1 and No. 2 are fed with steam from heating extractions, and the remaining five - from unregulated extractions after 9, 11, 14, 17, 19 stages.

Capacitors

The main purpose of the condensing device is to condense the exhaust steam of the turbine and ensure optimal steam pressure behind the turbine under nominal operating conditions.

In addition to maintaining the exhaust steam pressure at the level required for economical operation of the turbine unit, it ensures that the exhaust steam condensate is maintained and its quality meets the requirements of the PTE and the absence of overcooling in relation to the saturation temperature in the condenser.

Technical data of the capacitor 65KTSST:

Heat transfer surface, m 3 3000

Number of cooling pipes, pcs. 5470

Inner and outer diameter, mm 23/25

Length of condenser pipes, mm 7000

Pipe material - copper-nickel alloy MNZh5-1

Nominal cooling water flow, m 3 /h 8000

Number of cooling water strokes, pcs. 2

Number of cooling water flows, pcs. 2

Condenser weight without water, t. 60.3

Weight of the condenser with filled water space, t 92.3

Mass of the condenser with filled vapor space during hydrotesting, t 150.3

The pipe cleanliness factor adopted in the thermal calculation of the condenser is 0.9

Cooling water pressure, MPa (kgf/cm2) 0.2(2.0)

MINISTRY OF ENERGY AND ELECTRIFICATION OF THE USSR

MAIN TECHNICAL DIRECTORATE FOR OPERATION OF ENERGY SYSTEMS

I CONFIRM:

Deputy Head of the Main Technical Directorate

TYPICAL

ENERGY CHARACTERISTICS OF THE TURBO UNIT

T-50-130 TMZ

RD 34.30.706

UDC 621.165-18

Compiled by Sibtekhenergo with the participation of the Moscow parent enterprise "Soyuztechenergo"

APPLICATION

1. The typical energy characteristic of the T-50-130 TMZ turbine unit is compiled on the basis of thermal tests of two turbines (carried out by Yuzhtekhenergo at the Leningradskaya CHPP-14 and Sibtekhenergo at the Ust-Kamenogorskaya CHPP) and reflects the average efficiency of a turbine unit that has undergone a major overhaul, operating according to the factory design thermal scheme (graph T-1) and under the following conditions taken as nominal:

The pressure and temperature of fresh steam in front of the turbine stop valves are, respectively, 130 kgf/cm2* and 555 °C;

The maximum permissible fresh steam consumption is 265 t/h;

The maximum permissible steam flow through the switchable compartment and low-pressure pump is 165 and 140 t/h, respectively; the limit values ​​of steam flow through certain compartments correspond to technical specifications THAT;

Exhaust steam pressure:

a) for the characteristics of the condensation mode with constant pressure and the characteristics of work with selections for two- and one-stage heating of network water - 0.05 kgf/cm2;

b) to characterize the condensation mode at a constant flow rate and temperature of cooling water in accordance with the thermal characteristics of the condenser K at W=7000 m3/h and Elektrosila";

The pressure control range in the upper heating extraction is 0.6-2.5 kgf/cm2, and in the lower one - 0.5-2.0 kgf/cm2;

Heating of network water in the heating plant is 47 °C.

The test data underlying this energy characteristic was processed using the “Tables of Thermophysical Properties of Water and Water Steam” (Publishing House of Standards, 1960).

The condensate from the heating steam of high-pressure heaters is drained in cascade into HPH No. 5, and from it is supplied to the deaerator 6 kgf/cm2. When the steam pressure in selection chamber III is below 9 kgf/cm2, the heating steam condensate from HPH No. 5 is sent to HDPE No. 4. Moreover, if the steam pressure in selection chamber II is above 9 kgf/cm2, the heating steam condensate from HPH No. 6 is sent to deaerator 6 kgf/cm2.

The condensate of the heating steam of the low-pressure heaters is drained in cascade into the HDPE No. 2, from which it is supplied by drain pumps to the main condensate line behind the HDPE No. 2. The heating steam condensate from the HDPE No. 1 is drained into the condenser.

The upper and lower heating water heaters are connected to turbine outlets VI and VII, respectively. The condensate of the heating steam from the upper network water heater is supplied to the main condensate line behind the HDPE No. 2, and from the lower one - into the main condensate line behind the HDPE No. 1.

2. The turbine unit, along with the turbine, includes the following equipment:

Generator type TV-60-2 from the Elektrosila plant with hydrogen cooling;

Four low-pressure heaters: HDPE No. 1 and HDPE No. 2 of the PN type, HDPE No. 3 and HDPE No. 4 of the PN type;

Three high-pressure heaters: PVD No. 5 of PVM type, PVD No. 6 of PVM type, PVD No. 7 of PVM type;

Surface two-pass capacitor K;

Two main three-stage ESA ejectors and one starting one (one main ejector is constantly in operation);

Two network water heaters (upper and lower) PSS;

Two condensate pumps 8KsD-6x3 driven by electric motors with a power of 100 kW (one pump is constantly in operation, the other is in reserve);

Three condensate pumps of network water heaters 8KsD-5x3 driven by electric motors with a power of 100 kW each (two pumps are in operation, one is in reserve).

3. In the condensing mode of operation with the pressure regulator turned off, the total gross heat consumption and fresh steam consumption, depending on the power at the generator terminals, are analytically expressed by the following equations:

At constant steam pressure in the condenser R 2 = 0.05 kgf/cm2 (graph T-22, b)

Q 0 = 10,3 + 1,985 Nt + 0,195 (Nt- 45.44) Gcal/h; (1)

D 0 = 10,8 + 3,368 Nt + 0,715 (Nt- 45.44) t/h; (2)

At constant flow (W= 7000 m3/h) and temperature ( = 20 °C) of cooling water (graph T-22, a);

Q 0 = 10,0 + 1,987 Nt + 0,376 (Nt- 45.3) Gcal/h; (3)

D 0 = 8,0 + 3,439 Nt + 0,827 (Nt- 45.3) t/h. (4)

The consumption of heat and fresh steam for the power specified under operating conditions is determined from the above dependencies with the subsequent introduction of the necessary corrections (graphs T-41, T-42, T-43); these amendments take into account deviations of operating conditions from nominal (from characteristic conditions).

The system of correction curves practically covers the entire range of possible deviations of the operating conditions of the turbine unit from the nominal ones. This makes it possible to analyze the operation of a turbine unit under power plant conditions.

The corrections are calculated for the condition of maintaining constant power at the generator terminals. If there are two or more deviations from the nominal operating conditions of the turbogenerator, the corrections are algebraically summed up.

4. In the mode with district heating extraction, the turbine unit can operate with one-, two- and three-stage heating of network water. The corresponding typical mode diagrams are shown in graphs T-33 (a-d), T-33A, T-34 (a-k), T-34A and T-37.

The diagrams indicate the conditions for their construction and the rules of use.

Typical mode diagrams allow you to directly determine for the accepted initial conditions ( Nt, Qt, Pt) steam flow to the turbine.

Graphs T-33 (a-d) and T-34 (a-k) show a diagram of modes expressing the dependence D 0 = f (Nt, Qt) at certain values pressure in regulated extractions.

It should be noted that the mode diagrams for one- and two-stage heating of network water, expressing the dependence D 0 = f (Nt, Qt, Pt) (graphs T-33A and T-34A) are less accurate due to certain assumptions made in their construction. These mode diagrams can be recommended for use when approximate calculations. When using them, it should be borne in mind that the diagrams do not clearly indicate the boundaries defining all possible modes (according to the maximum steam flow rates through the corresponding sections of the turbine flow path and the maximum pressures in the upper and lower extractions).

For more precise definition values ​​of steam flow to the turbine for a given thermal and electrical load and steam pressure in the controlled extraction, as well as determining the zone of permissible operating modes, one should use the mode diagrams presented in graphs T-33 (a-d) and T-34 (a-k) .

Specific heat consumption for electricity production for the corresponding operating modes should be determined directly from graphs T-23 (a-d) - for single-stage heating of network water and T-24 (a-k) - for two-stage heating of network water.

These graphs are constructed based on the results of special calculations using the characteristics of the turbine and heating plant flow sections and do not contain inaccuracies that appear when constructing regime diagrams. Calculation of specific heat consumption for electricity generation using mode diagrams gives a less accurate result.

To determine the specific heat consumption for the production of electricity, as well as the steam consumption per turbine according to graphs T-33 (a-d) and T-34 (a-k) at pressures in regulated extractions for which graphs are not directly given, the interpolation method should be used .

For the operating mode with three-stage heating of network water, the specific heat consumption for electricity production should be determined according to schedule T-25, which is calculated according to the following relationship:

kcal/(kWh), (5)

Where Qetc- constant other heat losses, for 50 MW turbines, taken equal to 0.61 Gcal/h, according to the "Instructions and methodological instructions on standardization of specific fuel consumption at thermal power plants" (BTI ORGRES, 1966).

The T-44 graphs show corrections to the power at the generator terminals when the operating conditions of the turbine unit deviate from the nominal ones. When the exhaust steam pressure in the condenser deviates from the nominal value, the power correction is determined using the vacuum correction grid (graph T-43).

The signs of the corrections correspond to the transition from the conditions for constructing the regime diagram to operational conditions.

If there are two or more deviations of the operating conditions of the turbine unit from the nominal ones, the corrections are algebraically summed up.

Corrections to power for fresh steam parameters and return water temperature correspond to the factory calculation data.

In order to maintain a constant amount of heat supplied to the consumer ( QT=const) when changing the parameters of fresh steam, it is necessary to make an additional correction to the power, taking into account the change in steam flow into the extraction due to a change in the enthalpy of steam in the controlled extraction. This amendment is determined by the following dependencies:

When working according to an electrical schedule and a constant steam flow to the turbine:

kW; (7)

When working according to the heat schedule:

kg/h; (9)

The enthalpy of steam in the chambers of controlled heating extraction is determined according to graphs T-28 and T-29.

The temperature pressure of the network water heaters is taken according to the calculated TMZ data and is determined by the relative underheating according to schedule T-27.

When determining the heat utilization of network water heaters, the subcooling of the heating steam condensate is assumed to be 20 °C.

When determining the amount of heat perceived by the built-in beam (for three-stage heating of network water), the temperature pressure is assumed to be 6 °C.

The electric power developed in the heating cycle due to the release of heat from regulated extractions is determined from the expression

Ntf = Wtf · QT MW, (12)

Where Wtf- specific electricity production for the heating cycle under the appropriate operating modes of the turbine unit is determined according to schedule T-21.

The electrical power developed by the condensation cycle is determined as the difference

Nkn = Nt – Ntf MW. (13)

5. Method of determination specific consumption heat for electricity generation for various operating modes of the turbine unit when the specified conditions deviate from the nominal ones is explained by the following examples.

Example 1. Condensing mode with pressure regulator disabled.

Given: Nt= 40 MW, P 0 = 125 kgf/cm2, t 0 = 550 °C, R 2 = 0.06 kgf/cm2; thermal diagram - calculated.

It is required to determine the fresh steam consumption and gross specific heat consumption under given conditions ( Nt= 40 MW).

In table 1 shows the calculation sequence.

Example 2. Operating mode with controlled steam extraction with two- and single-stage heating of network water.

A. Operating mode according to thermal schedule

Given: Qt= 60 Gcal/h; Ptv= 1.0 kgf/cm2; R 0 = 125 kgf/cm2; t 0 = 545 °C, t2 = 55 °C; heating of network water - two-stage; thermal diagram - calculated; other conditions are nominal.

It is required to determine the power at the generator terminals, fresh steam consumption and gross specific heat consumption under given conditions ( Qt= 60 Gcal/h).

In table 2 shows the calculation sequence.

The operating mode for single-stage heating of network water is calculated in a similar way.

Table 1

table 2

Russian FederationRD

Regulatory characteristics turbine condensers T-50-130 TMZ, PT-60-130/13 and PT-80/100-130/13 LMZ

When compiling the “Regulatory Characteristics”, the following basic designations were adopted:

Steam consumption to the condenser (steam load of the condenser), t/h;

Standard steam pressure in the condenser, kgf/cm*;

Actual steam pressure in the condenser, kgf/cm;

Cooling water temperature at the condenser inlet, °C;

Cooling water temperature at the condenser outlet, °C;

Saturation temperature corresponding to the steam pressure in the condenser, °C;

Hydraulic resistance of the condenser (pressure drop of cooling water in the condenser), mm water column;

Standard temperature pressure of the condenser, °C;

Actual temperature difference of the condenser, °C;

Heating of cooling water in the condenser, °C;

Nominal design flow rate of cooling water into the condenser, m/h;

Cooling water flow into the condenser, m/h;

Total condenser cooling surface, m;

Cooling surface of the condenser with the built-in condenser bank disconnected by water, m.

Regulatory characteristics include the following main dependencies:

1) temperature difference of the condenser (°C) from the steam flow into the condenser (steam load of the condenser) and the initial temperature of the cooling water at the nominal flow of cooling water:

2) steam pressure in the condenser (kgf/cm) from the steam flow into the condenser and the initial temperature of the cooling water at the nominal cooling water flow:

3) temperature difference of the condenser (°C) from the steam flow into the condenser and the initial temperature of the cooling water at a cooling water flow rate of 0.6-0.7 nominal:

4) steam pressure in the condenser (kgf/cm) from the steam flow into the condenser and the initial temperature of the cooling water at a cooling water flow rate of 0.6-0.7 - nominal:

5) temperature difference of the condenser (°C) from the steam flow into the condenser and the initial temperature of the cooling water at a cooling water flow rate of 0.44-0.5 nominal;

6) steam pressure in the condenser (kgf/cm) from the steam flow into the condenser and the initial temperature of the cooling water at a cooling water flow rate of 0.44-0.5 nominal:

7) hydraulic resistance of the condenser (pressure drop of cooling water in the condenser) from the flow of cooling water during operational clean surface condenser cooling;

8) corrections to turbine power for deviation of exhaust steam pressure.

Turbines T-50-130 TMZ and PT-80/100-130/13 LMZ are equipped with condensers, in which about 15% of the cooling surface can be used to heat make-up or return network water (built-in bundles). It is possible to cool the built-in bundles with circulating water. Therefore, in the “Regulatory Characteristics” for turbines of the T-50-130 TMZ and PT-80/100-130/13 LMZ types, the dependences according to paragraphs 1-6 are also given for condensers with disconnected built-in bundles (with a cooling surface reduced by approximately 15% condensers) at cooling water flow rates of 0.6-0.7 and 0.44-0.5.

For the PT-80/100-130/13 LMZ turbine, the characteristics of the condenser with the built-in beam turned off at a cooling water flow rate of 0.78 nominal are also given.

3. OPERATIONAL CONTROL OF THE OPERATION OF THE CONDENSING UNIT AND THE CONDITION OF THE CONDENSER

The main criteria for assessing the operation of a condensing unit, characterizing the condition of the equipment at a given steam load of the condenser, are the steam pressure in the condenser and the temperature pressure of the condenser that meets these conditions.

Operational control over the operation of the condensing unit and the condition of the condenser is carried out by comparing the actual steam pressure in the condenser measured under operating conditions with the standard steam pressure in the condenser determined for the same conditions (the same steam load of the condenser, flow rate and temperature of the cooling water), as well as by comparing the actual temperature condenser pressure with standard.

Comparative analysis of measurement data and standard performance indicators of the installation makes it possible to detect changes in the operation of the condensing unit and establish probable reasons their.

A feature of turbines with controlled steam extraction is their long-term operation, with low steam flows into the condenser. In the mode with heating extraction, monitoring the temperature pressure in the condenser does not give a reliable answer about the degree of contamination of the condenser. Therefore, it is advisable to monitor the operation of the condensing unit when the steam flow into the condenser is at least 50% and when condensate recirculation is turned off; this will increase the accuracy of determining the steam pressure and temperature difference of the condenser.

In addition to these basic quantities, for operational monitoring and analysis of the operation of the condensing unit, it is also necessary to reliably determine a number of other parameters on which the exhaust steam pressure and temperature difference depend, namely: the temperature of the incoming and outgoing water, steam load condenser, cooling water flow, etc.

The influence of air suction in air removal devices operating within performance characteristics, and is insignificant, while the deterioration of air density and the increase in air suction, exceeding the operating capacity of the ejectors, have a significant impact on the operation of the condensing unit.

Therefore, monitoring the air density of the vacuum system of turbine units and maintaining air suction at the level of PTE standards is one of the main tasks during operation condensing units.

The proposed Standard characteristics are based on air suction values ​​that do not exceed PTE standards.

Below are the main parameters that need to be measured during operational monitoring of the condition of the capacitor, and some recommendations for organizing measurements and methods for determining the main controlled quantities.

3.1. Exhaust steam pressure

To obtain representative data on the condenser exhaust steam pressure under operating conditions, measurements must be made at the points specified in the Standard Specifications for each condenser type.

Exhaust steam pressure must be measured by liquid mercury instruments with an accuracy of at least 1 mmHg. (single-glass cup vacuum gauges, barovacuum tubes).

When determining the pressure in the condenser, it is necessary to introduce appropriate corrections to the instrument readings: for the temperature of the mercury column, for the scale, for capillarity (for single-glass instruments).

The pressure in the condenser (kgf/cm) when measuring vacuum is determined by the formula

Where is barometric pressure (as adjusted), mmHg;

Vacuum determined by vacuum gauge (with corrections), mm Hg.

The pressure in the condenser (kgf/cm) when measured with a barovacuum tube is determined as

Where is the pressure in the condenser, determined by the device, mm Hg.

Barometric pressure must be measured with a mercury inspector's barometer with the introduction of all corrections required according to the instrument's passport. It is also possible to use data from the nearest weather station, taking into account the difference in heights of the objects.

When measuring exhaust steam pressure, the laying of impulse lines and installation of instruments must be carried out in compliance with the following rules for installing instruments under vacuum:

• the internal diameter of the impulse tubes must be at least 10-12 mm;
• impulse lines must have a total slope towards the capacitor of at least 1:10;
• the tightness of the impulse lines must be checked by pressure testing with water;
• It is prohibited to use locking devices with seals and threaded connections;
• measuring devices must be connected to impulse lines using thick-walled vacuum rubber.

3.2. Temperature difference

Temperature difference (°C) is defined as the difference between the saturation temperature of the exhaust steam and the temperature of the cooling water at the condenser outlet

In this case, the saturation temperature is determined from the measured pressure of the exhaust steam in the condenser.

Monitoring the operation of condensing units of heating turbines should be carried out in the condensing mode of the turbine with the pressure regulator turned off in the production and heating extractions.

The steam load (steam flow into the condenser) is determined by the pressure in the chamber of one of the extractions, the value of which is the control.

The steam flow (t/h) into the condenser in condensing mode is equal to:

Where is the consumption coefficient, numeric value which is given in the technical data of the condenser for each type of turbine;

Steam pressure in the control stage (sampling chamber), kgf/cm.

If it is necessary to monitor the operation of the condenser in the heating mode of the turbine, the steam flow is determined approximately by calculation based on the steam flow to one of the intermediate stages of the turbine and the steam flow to the heating extraction and low-pressure regenerative heaters.

For the T-50-130 TMZ turbine, the steam flow (t/h) into the condenser in heating mode is:

• with single-stage heating of network water

• with two-stage heating of network water

Where and are the steam consumption, respectively, through the 23rd (for single-stage) and 21st (for two-stage heating of network water) stages, t/h;

Consumption of network water, m/h;

; - heating of network water in horizontal and vertical network heaters, respectively, °C; is defined as the temperature difference between the network water after and before the corresponding heater.

The steam flow through the 23rd stage is determined according to Fig. I-15, b, depending on the fresh steam flow to the turbine and the steam pressure in the lower heating extraction.

The steam flow through the 21st stage is determined according to Fig. I-15, a, depending on the fresh steam flow to the turbine and the steam pressure in the upper heating extraction.

For PT turbines, the steam flow (t/h) into the condenser in heating mode is:

• for turbines PT-60-130/13 LMZ

• for turbines PT-80/100-130/13 LMZ

Where is the steam consumption at the outlet of the CSD, t/h. Determined according to Fig. II-9 depending on the steam pressure in the heating extraction and in the V extraction (for PT-60-130/13 turbines) and according to Fig. III-17 depending on the steam pressure in the heating extraction and in the IV extraction ( for turbines PT-80/100-130/13);

Water heating in network heaters, °C. Determined by the temperature difference between the network water after and before the heaters.

The pressure accepted as the control pressure must be measured with spring instruments of accuracy class 0.6, periodically and carefully checked. To determine the true value of pressure in the control stages, it is necessary to introduce appropriate corrections to the instrument readings (for the installation height of the instruments, correction according to the passport, etc.).

The flow rates of fresh steam to the turbine and network water, necessary to determine the steam flow rate to the condenser, are measured by standard flow meters with corrections for deviations of the operating parameters of the medium from the calculated ones.

The temperature of the network water is measured by mercury laboratory thermometers with a division value of 0.1 °C.

3.4. Cooling water temperature

The cooling water temperature entering the condenser is measured at one point on each penstock. The water temperature at the outlet of the condenser must be measured at at least three points in one cross section of each drain conduit at a distance of 5-6 m from the outlet flange of the condenser and determined as the average based on thermometer readings at all points.

The temperature of the cooling water must be measured by mercury laboratory thermometers with a division value of 0.1 °C, installed in thermometric sleeves with a length of at least 300 mm.

3.5. Hydraulic resistance

Control of contamination of tube sheets and condenser tubes is carried out by the hydraulic resistance of the condenser through the cooling water, for which the pressure difference between the pressure and drain pipes of the condensers is measured using a mercury double-glass U-shaped differential pressure gauge installed at a level below the pressure measurement points. Impulse lines from pressure and drain pipes capacitors must be filled with water.

The hydraulic resistance (mm water column) of the condenser is determined by the formula

Where is the difference measured by the device (adjusted for the temperature of the mercury column), mm Hg.

When measuring the hydraulic resistance, the flow of cooling water into the condenser is also determined to allow comparison with the hydraulic resistance according to the Standard characteristics.

3.6. Cooling water flow

The cooling water flow to the condenser is determined by the thermal balance of the condenser or by direct measurement by segmental diaphragms installed on the pressure supply water lines. Cooling water flow (m/h) based on the thermal balance of the condenser is determined by the formula

Where is the difference in heat content of exhaust steam and condensate, kcal/kg;

Heat capacity of cooling water, kcal/kg·°С, equal to 1;

Density of water, kg/m, equal to 1.

When drawing up the Standard Characteristics, it was taken to be 535 or 550 kcal/kg, depending on the operating mode of the turbine.

3.7. Air density of vacuum system

The air density of the vacuum system is controlled by the amount of air at the exhaust of the steam jet ejector.

4. ASSESSMENT OF THE REDUCTION IN THE POWER OF A TURBINE UNIT DURING OPERATION WITH A REDUCED COMPARED TO THE STANDARD VACUUM

Condenser pressure deviation steam turbine from the standard one leads, for a given heat consumption to the turbine unit, to a decrease in the power developed by the turbine.

The change in power when the absolute pressure in the turbine condenser differs from its standard value is determined from experimentally obtained correction curves. The correction graphs included in these Capacitor Specifications show the change in power for different meanings steam flow rate in the low pressure turbine. For this mode of the turbine unit is determined and the value of the change in power is taken from the corresponding curve when the pressure in the condenser changes from to .

This value of the change in power serves as the basis for determining the excess of the specific heat consumption or specific fuel consumption established at a given load for the turbine.

For turbines T-50-130 TMZ, PT-60-130/13 and PT-80/100-130/13 LMZ, the steam flow rate in the ChND for determining the underproduction of turbine power due to an increase in pressure in the condenser can be taken equal to the steam flow rate in capacitor.

I. NORMATIVE CHARACTERISTICS OF CONDENSER K2-3000-2 TURBINES T-50-130 TMZ

1. Capacitor technical data

Cooling surface area:

• in condensation mode - according to the steam pressure in the IV selection:

2.3. The difference in heat content of exhaust steam and condensate () is taken as follows:

Figure I-1. Dependence of temperature pressure on steam flow into the condenser and cooling water temperature:

7000 m/h; =3000 m

Figure I-2. Dependence of temperature pressure on steam flow into the condenser and cooling water temperature:

5000 m/h; =3000 m

Figure I-3. Dependence of temperature pressure on steam flow into the condenser and cooling water temperature:

3500 m/h; =3000 m

Figure I-4. Dependence of absolute pressure on steam flow into the condenser and cooling water temperature:

7000 m/h; =3000 m

Figure I-5. Dependence of absolute pressure on steam flow into the condenser and cooling water temperature:

5000 m/h; =3000 m

Figure I-6. Dependence of absolute pressure on steam flow into the condenser and cooling water temperature:

3500 m/h; =3000 m

Figure I-7. Dependence of temperature pressure on steam flow into the condenser and cooling water temperature:

7000 m/h; =2555 m

Figure I-8. Dependence of temperature pressure on steam flow into the condenser and cooling water temperature:

5000 m/h; =2555 m

Figure I-9. Dependence of temperature pressure on steam flow into the condenser and cooling water temperature:

3500 m/h; =2555 m

Figure I-10. Dependence of absolute pressure on steam flow into the condenser and cooling water temperature:

7000 m/h; =2555 m

Figure I-11. Dependence of absolute pressure on steam flow into the condenser and cooling water temperature:

5000 m/h; =2555 m

Figure I-12. Dependence of absolute pressure on steam flow into the condenser and cooling water temperature:

3500 m/h; =2555 m

Figure I-13. Dependence of hydraulic resistance on the flow of cooling water into the condenser:

1 - full surface of the capacitor; 2 - with the built-in beam disabled

Figure I-14. Correction to the power of the T-50-130 TMZ turbine for deviation of the steam pressure in the condenser (according to the “Typical energy characteristics of the T-50-130 TMZ turbine unit.” M.: SPO Soyuztekhenergo, 1979)

Fig.l-15. Dependence of steam flow through the T-50-130 TMZ turbine on fresh steam flow and pressure in the upper heating selection (with two-stage heating of network water) and pressure in the lower heating selection (with single-stage heating of network water):

a - steam flow through the 21st stage; b - steam flow through the 23rd stage

II. NORMATIVE CHARACTERISTICS OF CONDENSER 60KTSS TURBINE PT-60-130/13 LMZ

1. Technical data

Air removal device - two steam jet ejectors EP-3-700

2. Instructions for determining some parameters of the condensing unit

2.1. The exhaust steam pressure in the condenser is determined as the average value of two measurements.

The location of the vapor pressure measurement points in the condenser neck is shown in the diagram. The pressure measurement points are located in a horizontal plane passing 1 m above the plane of connection of the condenser with the adapter pipe.

2.2. Determine the steam flow into the condenser:

• in condensation mode - by steam pressure in the V selection;

• in heating mode - in accordance with the instructions in Section 3.

2.3. The difference in heat content of exhaust steam and condensate () is taken as follows:

• for condensation mode 535 kcal/kg;
• for heating mode 550 kcal/kg.

Fig.II-1. Dependence of temperature pressure on steam flow into the condenser and cooling water temperature:

Fig.II-2. Dependence of temperature pressure on steam flow into the condenser and cooling water temperature:

Fig.II-3. Dependence of temperature pressure on steam flow into the condenser and cooling water temperature:

Fig.II-4. Dependence of absolute pressure on steam flow into the condenser and cooling water temperature:

Fig.II-5. Dependence of absolute pressure on steam flow into the condenser and cooling water temperature:

Fig.II-6. Dependence of absolute pressure on steam flow into the condenser and cooling water temperature.