T 50 130 cooling and heating turbine. Design and technical characteristics of equipment of LLC 'Lukoil-Volgogradenergo' Volzhskaya CHPP

1. A 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) 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;

* Absolute pressure is given in the text and graphs.

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; limit values steam flow through certain compartments corresponds to technical specifications TU 24-2-319-71;

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/cm 2 ;

b) to characterize the condensation regime at a constant flow rate and temperature of cooling water in accordance with the thermal characteristics of the K-2-3000-2 condenser at W = 7000 m 3 / h and t in 1 = 20 °C - (graph);

c) for the operating mode with steam extraction with three-stage heating of network water - in accordance with the schedule;

The high and low pressure regeneration system is fully enabled; steam from selections III or II is supplied to the deaerator 6 kgf/cm2 (as the steam pressure in the chamber decreasesIII selection up to 7 kgf/cm 2 steam to the deaerator is supplied from II selection);

Feed water consumption is equal to fresh steam consumption;

The temperature of the feed water and the main turbine condensate behind the heaters corresponds to the dependencies shown in the graphs and ;

The increase in enthalpy of feed water in the feed pump is 7 kcal/kg;

Efficiency electric generator corresponds to the warranty data of the Elektrosila plant;

The pressure control range in the upper heating selection is 0.6 - 2.5 kgf/cm 2, and in the lower one - 0.5 - 2.0 kgf/cm 2;

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, 1969).

Condensate from heating steam heaters high pressure drains cascade into HPH No. 5, and from it is supplied to the deaerator 6 kgf/cm 2 . At steam pressure in the chamber III extraction below 9 kgf/cm 2, the heating steam condensate from HPH No. 5 is sent to HPH 4. In this case, if the steam pressure in the chamber II extraction above 9 kgf/cm 2 , the heating steam condensate from HPH No. 6 is sent to the deaerator 6 kgf/cm 2 .

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

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

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, type PN-100-16-9, HDPE No. 3 and HDPE No. 4, type PN-130-16-9;

Three high-pressure heaters: PVD No. 5 type PV-350-230-21M, PVD No. 6 type PV-350-230-36M, PVD No. 7 type PV-350-230-50M;

Surface two-way capacitor K2-3000-2;

Two main three-stage ejectors EP-3-600-4A and one starting one (one main ejector is constantly in operation);

Two network water heaters (upper and lower) PSS-1300-3-8-1;

Two condensate pumps 8KsD-6´ 3 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-5´ 3 driven by electric motors with a power of 100 kW each (two pumps are in operation, one is in reserve).

3. In 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 P 2 = 0.05 kgf/cm 2 (graph, b)

Q o = 10.3 + 1.985N t + 0.195 (N t - 45.44) Gcal/h;

D o = 10.8 + 3.368 N t + 0.715 (N t - 45.44) t/h; (2)

At constant flow ( W = 7000 m 3 /h) and temperature ( t at 1 = 20 °C) cooling water (graph, A):

Q o = 10.0 + 1.987 N t + 0.376 (N t - 45.3) Gcal/h; (3)

D o = 8.0 + 3.439 N t + 0.827 (N t - 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 , , ); 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 (a - d), , (a - j), A and .

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 (N t , Q t , Р t) steam flow to the turbine.

On graphs (a - d) and T-34 (a - j) shows mode diagrams expressing the dependence D o = f (N t , Q t ) at certain pressure values in regulated extractions.

It should be noted that the mode diagrams for one- and two-stage heating of network water, expressing the dependence D o = f (N t , Q t , R t) (graphs and A) are less accurate due to certain assumptions made in their construction. These mode diagrams can be recommended for use in 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).

To more accurately determine the value of steam flow to the turbine for a given thermal and electrical load and steam pressure in the controlled outlet, as well as to determine the zone of permissible operating modes, you should use the mode diagrams presented on the graphs(a - d) and (a - j).

Specific heat consumption for electricity production for the corresponding operating modes should be determined directly from the graphs(a - d) - for single-stage heating of network water and (a - j)- 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 specific heat consumption for electricity production, as well as steam consumption per turbine using graphs(a - d) and (a - j) at pressures in controlled extractions for which graphs are not directly provided, the interpolation method should be used.

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

q t = 860 (1 + ) + kcal/(kW× h), (5)

where Q pr - 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 signs of the corrections correspond to the transition from the conditions for constructing the regime diagram to operational ones.

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 ( Q t = 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:

D = -0.1 Q t (P o - ) kW; (6)

D = +0.1 Q t (t o - ) kW; (7)

When working according to the thermal schedule:

D = +0.343 Q t (P o - ) kW; (8)

D = -0.357 Q t (t o - ) kW; (9) T-37.

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

N tf = W tf × Q t MW, (12)

where W tf - specific electricity production for the heating cycle under the appropriate operating modes of the turbine unit is determined according to the schedule.

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

N kn = N t - N tf MW. (13)

5. Methodology for determining the specific heat consumption for electricity generation for different modes The operation of a turbine unit when the specified conditions deviate from the nominal ones is explained by the following examples.

Example 1. Condensation mode with the pressure regulator turned off.

Given: N t = 40 MW, P o = 125 kgf/cm 2, t o = 550 °C, P 2 = 0.06 kgf/cm 2 ; thermal diagram - calculated.

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

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

A. Operating mode according to thermal schedule

Given: Q t = 60 Gcal/h; R TV = 1.0 kgf/cm 2; P o = 125 kgf/cm 2 ; t o = 545 °C; t 2 = 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 ( Q t = 60 Gcal/h).

In table The calculation sequence is given.

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

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 rate of cooling water with an operationally clean cooling surface of the condenser;

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 evaluating work condensing unit, which characterize the state 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 comparing the actual temperature condenser pressure with standard.

A 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 their probable causes.

A feature of turbines with controlled steam extraction is their long-term operation, with low steam flows into the condenser. In the mode with district 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 a 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 incoming and outgoing water, the steam load of the condenser, the flow rate of cooling water 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 in the operation of 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 the installation of instruments must be carried out in compliance with following rules installation of devices under vacuum:

internal diameter 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) to 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 from 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 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 temperature of the water leaving the condenser must be measured at at least three points in one cross section 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 the pressure and drain pipes of the condensers 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 simultaneously 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 POWER OF A TURBINE PLANT DURING OPERATION WITH A REDUCED VACUUM COMPARED TO THE STANDARD VACUUM

The deviation of the pressure in the condenser of a 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 the Standard Capacitor Characteristics data show the change in power for various values of steam flow in the turbine low-pressure pump. For a given mode of the turbine unit, the value of the change in power when the pressure in the condenser changes from to is determined from the corresponding curve.

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:


without built-in beam


Tube diameter:
outer
interior
Number of tubes
Number of water strokes
Number of threads
Air removal device - two steam jet ejectors EP-3-2

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

Total cooling surface area
Nominal steam flow to the condenser
Estimated amount of cooling water
Active length of condenser tubes Tube diameter:
outer
interior
Number of tubes
Number of water strokes
Number of threads

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.

Cogeneration turbines with a capacity of 40-100 MW

Cogeneration turbines with a capacity of 40-100 MW for initial steam parameters of 130 kgf/cm2, 565ºС are designed as a single series, united by common basic solutions, unity of design and broad unification of components and parts.

Turbine T-50-130 with two heating steam extractions at 3000 rpm, rated power 50 MW. Subsequently, the rated power of the turbine was increased to 55 MW while simultaneously improving the turbine's efficiency guarantee.

The T-50-130 turbine is made of two cylinders and has a single-flow exhaust. All extractions, regenerative and heating, together with the exhaust pipe are placed in one low-pressure cylinder. In the high-pressure cylinder, steam expands to the pressure of the upper regenerative extraction (about 34 kgf/cm2), in the low-pressure cylinder - to the pressure of the lower heating extraction

For the T-50-130 turbine, it was optimal to use a two-crown control wheel with a limited isentropic difference and perform the first group of stages with a small diameter. The high pressure cylinder of all turbines has 9 stages - control and 8 pressure stages.

Subsequent stages located in a medium or low pressure cylinder have a higher volumetric steam flow rate and are made with larger diameters.

All stages of the turbines of the series have aerodynamically developed profiles; for the control stage of the high-pressure engine, blades from the Moscow Energy Institute with radial profiling of the nozzle and working grids were adopted.

Blading of the CVP and CSD is performed with radial and axial tendrils, which made it possible to reduce the gaps in the flow part.

The high-pressure cylinder is made counter-flow relative to the medium-pressure cylinder, which made it possible to use one thrust bearing and a rigid coupling while maintaining relatively small axial clearances in the flow part of both the HPC and the LPC (or the LPC for 50 MW turbines).

The implementation of heating turbines with one thrust bearing was facilitated by the balancing of the main part of the axial force achieved in the turbines within each individual rotor and the transfer of the remaining, limited in magnitude, force to the bearing operating in both directions. In heating turbines, unlike condensing turbines, axial forces are determined not only by the steam flow rate, but also by the pressures in the steam extraction chambers. Significant changes in the forces along the flow path take place in turbines with two heating extractions when the outside air temperature changes. Since the steam flow remains unchanged, this change in the axial force practically cannot be compensated by the dummis and is completely transferred to the thrust bearing. Factory study of alternating turbine operation, as well as bifurcation

T-50-130 TMZ

TYPICAL
ENERGY CHARACTERISTICS
TURBO UNIT

T-50-130 TMZ

SERVICE OF EXCELLENCE AND INFORMATION SOYUZTEKHENERGO

MOSCOW 1979

MAIN FACTORY DATA OF THE TURBO UNIT
(TU 24-2-319-71)

* Taking into account the heat of the steam entering the condenser.

Comparison of the results of the typical characteristics data with the TMZ warranty data

Indicator

Heat transferred to the consumer Q t, Gcal/h
Turbine operating mode		Condensation	Single stage	Two stage
TMZ data

Fresh steam temperature tо, °С

Generator efficiency h, %


Cooling water temperature at the condenser inlet t in 1, °C
Cooling water flow W, m 3 /h
Specific steam consumption d, kg/(kW? h)
Typical data
Fresh steam pressure P o, kgf/cm 2
Fresh steam temperature t o , °C
Pressure in regulated extraction P, kgf/cm 2
Generator efficiency h, %
Temperature of feed water behind HPH No. 7 t p.v., °C
Temperature of network water at the inlet to the PSG heater t 2, °C
Exhaust steam pressure P 2, kgf/cm 2		t in 1 = 20 °C, W = 7000 m 3 / h
Specific steam consumption d e, kg/(kW? h)
Amendment to specific steam consumption for deviation of standard characteristics from warranty conditions
for deviation of exhaust steam pressure Dd e, kg/(kWh)
for deviation of feedwater temperature Dd e, kg/(kW? h)
for temperature deviation of return network water Dd e, kg/(kW? h)
Total correction to specific steam consumption Dd e, kg/(kW? h)
Specific steam consumption under warranty conditions dne, kg/(kW? h)
Deviation of specific steam consumption from the guarantee ad e, %
Average deviation ad e, %
* Extraction pressure regulator is switched off.
	PRINCIPAL THERMAL DIAGRAM OF A TURBO UNIT				Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

STEAM DISTRIBUTION DIAGRAM

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

STEAM PRESSURE IN EXTRACTION CHAMBERS UNDER CONDENSATION MODE

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT			Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT STEAM PRESSURE IN EXTRACTION CHAMBERS UNDER HEATING MODE	Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

STEAM PRESSURE IN EXTRACTION CHAMBERS UNDER HEATING MODE

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

TEMPERATURE AND ENTHALPY OF FEEDWATER BEYOND HIGH PRESSURE HEATERS

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT CONDENSATE TEMPERATURE BEYOND HDPE No. 4 WITH TWO- AND THREE-STAGE HEATING OF NETWORK WATER		Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT STEAM CONSUMPTION FOR HIGH PRESSURE HEATERS AND DEARATOR		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

STEAM CONSUMPTION FOR LOW PRESSURE HEATER No. 4

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

STEAM CONSUMPTION FOR LOW PRESSURE HEATER No. 3

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

STEAM LEAKAGES THROUGH THE FIRST COMPARTMENTS OF THE HPC, LPC SHAFT SEALS, STEAM SUPPLY TO THE END SEALS

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT EXTRACTIONS OF STEAM FROM SEALS INTO I, IV EXTRACTIONS, INTO THE PLATE HEATER AND COOLER			Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT STEAM CONSUMPTION THROUGH THE 21ST STAGE WITH TWO-STAGE HEATING OF NETWORK WATER	Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

STEAM CONSUMPTION THROUGH THE 23rd STAGE WITH SINGLE-STAGE HEATING OF NETWORK WATER

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

STEAM CONSUMPTION IN LPG IN CONDENSING MODE

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

STEAM FLOW IN LPG THROUGH A CLOSED DIAPHRAGM

Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT INTERNAL CAPACITY OF COMPARTMENTS 1 - 21		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT INTERNAL POWER OF COMPARTMENTS 1 - 23 WITH SINGLE-STAGE HEATING OF NETWORK WATER		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

INTERMEDIATE COMPARTMENT POWER

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

SPECIFIC ELECTRICITY PRODUCTION FROM THERMAL CONSUMPTION

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT TOTAL LOSSES OF TURBINE AND GENERATOR		Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT CONSUMPTION OF FRESH STEAM AND HEAT IN CONDENSING MODE WITH PRESSURE REGULATOR DISABLED		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS. TURBO UNIT

SPECIFIC GROSS HEAT CONSUMPTION FOR SINGLE-STAGE HEATING OF WATER NETWORKS

Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT	Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

SPECIFIC GROSS HEAT CONSUMPTION FOR TWO-STAGE HEATING OF NETWORK WATER

Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT SPECIFIC GROSS HEAT CONSUMPTION FOR TWO-STAGE HEATING OF NETWORK WATER		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT SPECIFIC HEAT CONSUMPTION DURING THREE-STAGE HEATING OF NETWORK WATER AND ELECTROMECHANICAL EFFICIENCY OF THE TURBO UNIT		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

TEMPERATURE DIFFERENCE

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

RELATIVE UNDERHEATING OF NETWORK WATER IN PSG AND PSV

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

ENTHALPY OF STEAM IN THE UPPER HEATING CHAMBER

Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT INTERMEDIATE COMPARTMENT HEAT DROP USED		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT HEAT USE IN THE NETWORK WATER HEATER (PSW)		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

CHARACTERISTICS OF CONDENSER K2-3000-2

Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT	Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT DIAGRAM OF MODES FOR SINGLE-STAGE HEATING OF NETWORK WATER		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT DIAGRAM OF MODES FOR SINGLE-STAGE HEATING OF NETWORK WATER		Type T-50-130 TMZ

Given: Q t = 60 Gcal/h; N t = 34 MW; R tn = 1.0 kgf/cm 2.

Determine: D about t/h.

Definition. On the diagram we find the given point A (Q t = 60 Gcal/h; N t = 34 MW). From point A, parallel to the inclined straight line, we go to the line set pressure(R tn = 1.0 kgf/cm 2). From the resulting point B we go in a straight line to the line of the given pressure (P tn = 1.0 kgf/cm2) of the right quadrant. From the resulting point B we lower the perpendicular to the flow axis. Point G corresponds to the determined fresh steam flow.

Given: Q t = 75 Gcal/h; R tn = 0.5 kgf/cm 2.

Determine: N t MW; D about t/h.

Definition. On the diagram we find the given point D (Q t = 75 Gcal/h; P t = 0.5 kgf/cm 2). From point D we go in a straight line to the power axis. Point E corresponds to the determined power. Then we go in a straight line to the line P tn = 0.5 kgf/cm 2 of the right quadrant. From point G we lower the perpendicular to the flow axis. The resulting point 3 corresponds to the determined fresh steam flow.

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT	Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT DIAGRAM OF MODES FOR TWO-STAGE HEATING OF NETWORK WATER		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT DIAGRAM OF MODES FOR TWO-STAGE HEATING OF NETWORK WATER		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

DIAGRAM OF MODES FOR TWO-STAGE HEATING OF NETWORK WATER

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

DIAGRAM OF MODES FOR TWO-STAGE HEATING OF NETWORK WATER

Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT DIAGRAM OF MODES FOR TWO-STAGE HEATING OF NETWORK WATER		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT DIAGRAM OF MODES FOR TWO-STAGE HEATING OF NETWORK WATER		Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

DIAGRAM OF MODES FOR TWO-STAGE HEATING OF NETWORK WATER

Type T-50-130 TMZ

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT

DIAGRAM OF MODES FOR TWO-STAGE HEATING OF NETWORK WATER

Type T-50-130 TMZ

		TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT DIAGRAM OF MODES FOR TWO-STAGE HEATING OF NETWORK WATER		Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT DIAGRAM OF MODES FOR TWO-STAGE HEATING OF NETWORK WATER

Asked by: Q T= 81 Gcal/h; N t = 57.2 MW; P TV= 1.4 kgf/cm2. Define: D0 t/h Definition. On the diagram we find the given point A ( Q t = 81 Gcal/h; N t = 57.2 MW). From point A, parallel to the inclined straight line, we go to the line of the given pressure ( P TV= 1.4 kgf/cm 2). From the obtained point B we go in a straight line to the line of the given pressure ( P T in= 1.4 kgf/cm 2) left quadrant. From the resulting point B we lower the perpendicular to the flow axis. Point G corresponds to the determined fresh steam flow.			Asked by: Q T= 73 Gcal/h; P T in= 0.8 kgf/cm2. Determine: N t MW; D 0 t/h Definition. Finding the given point D (QT= 73 Gcal/h; P T in = 0.8 kgf/cm 2) From point D we go in a straight line to the power axis. Point E corresponds to the determined power. Further in a straight line we go to the line P T in = 0.8 kgf/cm 2 left quadrant. From the resulting point Ж we lower the perpendicular to the flow axis. The resulting point 3 corresponds to the determined fresh steam flow.

		TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT		Type T-50-130 TMZ
b) Deviation of fresh steam pressure from the nominal V)
	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT AMENDMENTS TO FRESH STEAM CONSUMPTION IN CONDENSING MODE		Type T-50-130 TMZ

		TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT		Type T-50-130 TMZ
a) Deviation of fresh steam temperature from the nominal b) Deviation of fresh steam pressure from the nominal V) Deviation of feed water flow from the nominal
	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT AMENDMENTS TO SPECIFIC HEAT CONSUMPTION IN CONDENSING MODE		Type T-50-130 TMZ
d) For underheating of feed water in high-pressure heaters e) To change the heating of water in the feed pump f) To turn off a group of high-pressure heaters

TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT CORRECTION TO POWER FOR EXHAUST STEAM PRESSURE IN THE CONDENSER		Type T-50-130 TMZ

	TYPICAL ENERGY CHARACTERISTICS OF A TURBO UNIT AMENDMENTS TO POWER WHEN WORKING WITH HEATING COIL EXHAUSTS		Type T-50-130 TMZ

Given: Q t = 81 Gcal/h; N t = 57.2 MW; R TV = 1.4 kgf/cm 2.

Determine: D about t/h.

Definition. On the diagram we find the given point A (Q t = 81 Gcal/h; N t = 57.2 MW). From point A, parallel to the inclined straight line, we go to the line of the given pressure (P TV = 1.4 kgf/cm 2). From the resulting point B we go in a straight line to the line of the given pressure (P TV = 1.4 kgf/cm2) of the left quadrant. From the resulting point B we lower the perpendicular to the flow axis. Point G corresponds to the determined fresh steam flow.

Given: Q t = 73 Gcal/h; R TV = 0.8 kgf/cm 2.

Determine: N t MW; D about t/h.

Definition. We find the given point D (Q t = 73 Gcal/h; P t = 0.8 kgf/cm 2). From point D we go in a straight line to the power axis. Point E corresponds to the determined power. Then we go in a straight line to the line P TV = 0.8 kgf/cm 2 of the left quadrant. From the resulting point Ж we lower the perpendicular to the flow axis. The resulting point 3 corresponds to the determined fresh steam flow.

APPLICATION

1. A 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 accepted as nominal:

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

* Absolute pressure is given in the text and graphs.

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 the technical specifications of TU 24-2-319-71;

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/cm 2 ;

b) to characterize the condensation regime at a constant flow rate and temperature of cooling water in accordance with the thermal characteristics of the condenser K-2-3000-2 at W = 7000 m 3 / h and t in 1 = 20 ° C - (graph T-31);

c) for the operating mode with steam extraction with three-stage heating of network water - in accordance with schedule T-38;

The high and low pressure regeneration system is fully enabled; steam from selection III or II is supplied to the deaerator at 6 kgf/cm 2 (when the steam pressure in chamber III of selection decreases to 7 kgf/cm 2 steam is supplied to the deaerator from selection II);

Feed water consumption is equal to fresh steam consumption;

The temperature of the feed water and the main turbine condensate behind the heaters corresponds to the dependencies shown in graphs T-6 and T-7;

The increase in enthalpy of feed water in the feed pump is 7 kcal/kg;

The efficiency of the electric generator corresponds to the warranty data of the Elektrosila plant;

The pressure control range in the upper heating selection is 0.6 - 2.5 kgf/cm 2, and in the lower one - 0.5 - 2.0 kgf/cm 2;

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, 1969).

The condensate from the heating steam of the high-pressure heaters is drained in cascade into HPH No. 5, and from it is fed into the deaerator 6 kgf/cm 2 . When the steam pressure in selection chamber III is below 9 kgf/cm 2, the heating steam condensate from HPH No. 5 is directed to HPH 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 in the 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 heating water heater is supplied to the main condensate line behind the HDPE No. 2, and the lower - into the main condensate line behind the HDPE No. I.

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, type PN-100-16-9, HDPE No. 3 and HDPE No. 4, type PN-130-16-9;

Three high-pressure heaters: PVD No. 5 type PV-350-230-21M, PVD No. 6 type PV-350-230-36M, PVD No. 7 type PV-350-230-50M;

Surface two-way capacitor K2-3000-2;

Two main three-stage ejectors EP-3-600-4A and one starting one (one main ejector is constantly in operation);

Two network water heaters (upper and lower) PSS-1300-3-8-1;

Two condensate pumps 8KsD-6?3 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-5?3 driven by electric motors with a power of 100 kW each (two pumps are in operation, one is in reserve).

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

Q o = 10.3 + 1.985N t + 0.195 (N t - 45.44) Gcal/h; (1)

D o = 10.8 + 3.368 N t + 0.715 (N t - 45.44) t/h; (2)

At constant flow (W = 7000 m 3 / h) and temperature (t in 1 = 20 ° C) of cooling water (graph T-22, a):

Q o = 10.0 + 1.987 N t + 0.376 (N t - 45.3) Gcal/h; (3)

D o = 8.0 + 3.439 N t + 0.827 (N t - 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 diagrams indicate the conditions for their construction and the rules of use.

Typical mode diagrams make it possible to directly determine the steam flow to the turbine for the accepted initial conditions (N t, Q t, P t).

Graphs T-33 (a - d) and T-34 (a - j) show regime diagrams expressing the dependence D o = f (N t, Q t) at certain pressure values in regulated extractions.

It should be noted that the mode diagrams for one- and two-stage heating of network water, expressing the dependence D o = f(N t, Q t, P t) (graphs T-33A and T-34A), are less accurate due to certain assumptions, adopted during their construction. These mode diagrams can be recommended for use in 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).

To more accurately determine the value of steam flow to the turbine for a given thermal and electrical load and steam pressure in a controlled outlet, as well as to determine the zone of permissible operating modes, one should use the mode diagrams presented in graphs T-33 (a - d) and T-34 ( a - j).

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 - j) - for two-stage heating of network water.

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 - j) at pressures in regulated extractions, for which graphs are not directly given, the method should be used interpolation.

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:

q t = 860 (1 + ) + kcal/(kWh), (5)

where Q pr are constant other heat losses for 50 MW turbines, taken equal to 0.61 Gcal/h, according to the “Instructions and guidelines for standardizing 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. If 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 ones.

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 (Q t = const), when the parameters of fresh steam change, 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:

D = -0.1 Q t (P o - ) kW; (6)

D = +0.1 Q t (t o - ) kW; (7)

When working according to the thermal schedule:

D = +0.343 Q t (P o - ) kW; (8)

D = -0.357 Q t (t o - ) kW; (9)

D = +0.14 Q t (P o - ) kg/h; (10)

D = -0.14 Q t (t o - ) kg/h. (11)

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-37.

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

N tf = W tf? Q t MW, (12)

where W tf - specific electricity generation for the heating cycle under the corresponding 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

N kn = N t - N tf MW. (13)

5. The methodology for determining the specific heat consumption for electricity generation for various operating modes of a 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: N t = 40 MW, P o = 125 kgf/cm 2 , t o = 550 °C, P 2 = 0.06 kgf/cm 2 ; 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 for two- and one-stage heating of network water.

A. Operating mode according to thermal schedule

Given: Q t = 60 Gcal/h; R TV = 1.0 kgf/cm 2; P o = 125 kgf/cm 2 ; t o = 545 °C; t 2 = 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 (Q t = 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

Indicator	Designation	Dimension	Determination method	Received value
Fresh steam consumption per turbine at nominal conditions			Graph T-22 or equation (2)
Heat consumption per turbine at nominal conditions			Graph T-22 or equation (1)
Specific heat consumption at nominal conditions		kcal/(kWh)	Schedule T-22 or Q o / N t

practice report

6. Turbine T-50-130

Single-shaft steam turbine T-50-130 with a rated power of 50 MW at 3000 rpm with condensation and two heating steam extractions is designed to drive a generator AC, type TVF 60-2 with a power of 50 MW with 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.

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