Safety valves and its basic concepts






Pressure Relief Valve:This device is generally fitted on liquid lines like water, oil line. In this, valve the opening is proportional to increase in the line or vessel pressure. Hence the opening of valve is not sudden, but gradual if the pressure is increased gradually. In relief valve valves may not open 100%, as the line pressure reduces valves closes gradually. Pressure relief valves have higher flow capacities
Pressure Safety Valve: It is fitted on compressible fluid or gas lines. For such a valve the opening is sudden. When the set pressure of the valve is reached, the valve opens almost fully.
Pressure safety valve & relief valves are used for system, equipment & man power protection.
Pressure reducing valve: These may be of hydraulic or pneumatic type used for water lines. This valve reduces the pressure of the water that goes through it, and is used to obtaining a regulated and constant value at its outlet.
Pressure control valves: These may be of hydraulic or pneumatic type used for steam lines
Safety valve:
A safety valve must always be sized and able to vent any source of steam so that the pressure within the protected apparatus cannot exceed the maximum allowable accumulated pressure.Here the valves sizing, manufacturing, installation, positioning & setting are more important.
Factors to be considered for selection/design of a pressure safety valve:
  • Connection size and type
  • Operating pressure 
  • Operating Temperature
  • Back pressure
  • Service
  • Required capacity
  • Thermodisc
  • Thermal compensation
  • Blow down & Operating gap
Terminology used in safety valves:

Set pressure: It is the pressure at which safety valve lifts or pops up.It is usually 106-107% of operating pressure.

Reseat pressure: It is the pressure at which Safety valve seats.

Blowdown: It is the Blowdown is the difference between set pressure and reseating pressure of a safety valve expressed as a percentage of set pressure.

Blow down of safety valve = (Set pressure – Reseat pressure) X 100 / Set pressure

Blow down of safety valves is in the range of 2 to 5%.

Chattering: Excessive pressure loss at the inlet of the safety valve will cause extremely rapid opening and closing of the valve, this is called as chattering.

Chattering may result into lowered capacity as well as damage to the seating surface of the valve. Continuous chattering may result into damage to the other parts.

Following recommendation wil assists in eliminating the chattering
  • The area of the inlet nozzle should be equal to the the inlet area of safety valve & that nozzle should be short as possible
  • Inlet nozzle corners must be rounded to a radius of not less than ¼ of the diameter opening
Sonic Vibrations: Flashing, choked flow sudden flow or cut/off of steam in safet valves & related lines may result into  sonic vibration. This velocity is usually reached when the valve pressure drop rises to 50% of the upstream pressure. Vibration of long pipelines can also occur due to mechanical damage.
Precautions to avoid sonic vibrations:
  • Safety valve should be installed at least 8D to 10D of pipe diameter down stream from any bend in steam line.
  • Safety valves should not be installed closer than 8D to 10D to pipe diameters either upstream or down stream from the diverging or converging  “Y” fittings.
  • The safety valve nozzle should never be installed in a steam line in a position directly opposite a branch line of equivalent size.
Accumulating test pressure: The accumulation test is done on boilers to limit the excessive pressure rising while the safety valve is in open. The test is carried on new boilers or new safety valves with full firing condition with MSSV and feed water valves closed. It is conducted as long as water in drum permits generally 7 minutes for water tube boilers.



Consideration for installation of safety valve:
  • Exhaust drain & cover plate vent piping must be installed so that they will not impose under pressure on the safety valve.
         Note: Do not plug the cover plate hole or do not reduce the hole piping size.
  • Discharge pipe of the safety valve should not be supported on the valve body
  • Clearance between the valve exhaust piping and the discharge stack should be sufficient to prevent contact when considering thermal expansion of the boiler valve
  • Steam flowing vertically out of the discharge elbow produces a downward reaction on the elbow, in proportion on the quantity of steam flowing & its velocity.

  • In no case should discharge piping smaller than  the outlet valve

  • For optimum performance safety valves should be serviced regularly
  • Valve assembly should be within 10 vertical alignments.
  • Gaskets fitted should be of correct size, should not close the valve inlet opening

Adjustment of set pressure:
Safety valves are set +/- 1% of set pressure.Set pressure should not be changed without the permission of manufacturing unit.

Before proceeding to check the popping (lift) pressure, ensure the pressure gauges used are calibrated. To adjust the popping pressure, remove the lifting gear, exposing the adjusting bolt lock nut. Loosen the lock nut if the opening pressure is low tighten (turn clockwise) the adjusting bolt, if it is high loosen (turn counter clockwise) the bolt. After each adjustment the lock nut should be securely tightened to prevent loosening of the bolt.

Adjustment of blowdown:

If the blow down is not as desired when the set pressure has been obtained, it is must to adjust the rings. The guide (adjusting) ring is the principal blow down control ring. To change its position, remove the guide set screw on the back of the valve body. Insert a screw driver or similar tool and engage one of the notches (these can be seen through set screw hole). The ring can then be turned to the right or left as desired. Turning the guide (upper) ring to the right raises it up and reduces the blow down. Turning the guide (upper) ring to the left lowers it and increases the blow down. After each adjustment always replace and tighten the set screw being careful that its point engages a notch and does not rest on the top of the tooth.

Note: Do not attempt to adjust blow down with lower ring


Factors which cause safety valve to damage or failure:

  • Quantity & quality of the steam
  • Discharge piping stress and back pressure
  • Variation in ambient temperature
  • Improper gagging
  • Improper bolting of flanges
  • Foreign material in the steam
  • Improper method of assembly & disassembly

Guidelines for Boiler safety valve setting:

Preliminary checks
  • Ensure calibrated pressure & temperature gauges are fitted.
  • Gauges for each individual valves should be fitted
  • Discharge piping has to be inspected for binding on the valves,supports and welds on piping.
  • A rope appx. 6-7 meters with a hook one end should be attached to the valve lifting lever before starting the pressure rise. It will help in operating the lever to avoid chattering & over pressure
  • Have the correct tooling available
  • Establish the good communication system
Guidelines:
  • If the unit has Electromatic safety valve, this valve should be in operation firts for more safety of the unit.
  • Drum valves to should be tested first: Possibilities of valve part damage because of GIRL BLASTING are grater on superheated valves in contrast to the drum valves .If super heater valve is gagged after seat damage while testing other valves, the total valve damage will increase.

  • Boiler temperature increases during the testing cycle of the Drum valves. Consequently higher temperature steam will be available for super heater steam valves and produce accurate results
  • Keep water level low as possible, if drum level is high the safety valves may slugged with water causing long blow down & also may result damages to seat & disc.
  • Maintain pressure rising in the range of 2-3 kg/cm2 per minute, slow pressure rising may result into simmering of the valve.
  • If fuel feeding system fails at nearer set pressure, then reduce the boiler pressure at least 10% & raise again. Holding the boiler pressure nearer to set pressure for long time may result into simmering & valve lift erratically.
  • If a valve has to be lifted several times, cooling off period is very must. Cooling period is around 20-30 minutes.
  • If valves have not been tested with hydro test prior to the steam condition, it is recommended to hand lift before steam actuation.

Safety valve floating procedure:
  • Normally the highest set pressure valve is the valve floated first. While setting this valve other safety valves are gagged.
  • Start the boiler as per cold start up procedure by modulating the firing.                
  • When the drum pressure reaches about 60–70% of operating pressure gently tighten gage on other safety valve. 
  • Raise pressure slowly by throttling start up vent valve. When 80% of popping up pressure is reached manually operate the safety valve under test. This will blow off any debris or dust left over in the valve internals.
  • Raise the boiler pressure by modulating the firing
  • When the pressure reaches nearer to the set pressure close the start up vent. While the safety valve pops (lift), open the start up vent valve and note down the lifting/set pressure value.When the valve sits back, note down the reset pressure
  • Control of drum level is important to avoid possibility of water carry over from drum to the super heater.
  • The set pressure is adjusted by either tightening or loosening the adjusting nut. Tightening the nut increases the set pressure and vice versa
  •  Blow down is adjusted by upper rings adjustment.
  • After setting the set pressure and blow down, bring down the boiler pressure to operating level.
Examples-1: A boiler steam drum safety valve lifts at 125 kg/cm2 and reseats at 120 kg/cm2, then calculate its blow down percentage?
                                   BD% = (125 – 120) X 100/125
                                                 =4.0%

Example-2: A boiler super heater safety valve has blow down 3% & has been set at 70 kg/cm2, calculate the reseat pressure.

3% = (70-P2) X 100/70

Reseat pressure P2 =67.90 kg/cm2

Precautions shall be taken during Super heater safety valve set at lower operating temperature than actual:

Safety valves blow down should be set more than required, as blow down percentage decreases as the steam temperature increases. An approximate rule is to add 0.5% of set pressure to the blow down for each 56.5 °C rise in SH steam temperature.

Example-3:
If a Super heater safety valve lifts at 189.5 kg/cm2 & reseats at 180 kg/cm2 at the temperature of 400 deg c, then calculate the blowdown calculation at 540 deg c

We have,

Lift pressure        = 189.5 kg/cm2

Reseat pressure =180 kg/cm2

Difference           =9.5 kg/cm2

Difference in temperature =540-400 = 140 Deg C

Asper above condition for every 55.6 deg c  rise in steam temperature blow down percentage increases by 0.5% of set pressure

140/55.6  X 0.5 X 189.5/100

=2.385 kg/cm2

Hence, blow down  at 540 deg c =9.5-2.385 =7.115 kg/cm2


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STEAM CONDENSER,VACUUM AND CALCULATIONS




A steam condenser is device or an appliance in which steam condenses and heat released by steam is absorbed by water. Heat is basically shell & tube type heat exchanger, where cooling water passes through tubes & steam condenses in shell.

The functions of the condensers are:
  • It condenses the steam exhausted from Turbine last stage
  • Increase the thermal efficiency of the plant reducing the exhaust pressure and thereby reducing the exhaust temperature
  • It maintains a very low back pressure on the exhaust side of the Turbine
  • Supplies feed water to Boiler through deaerator

Condenser related components:
  • Hot well
  • Cooling water inlet & outlet system
  • Cooling tower
  • Support springs or expansion neck
  • Air Ejector system
  • Condensate extraction system
  • Cooling water tubes & tube sheet
  • Vacuum breaker valve
  • Safety valve or rapture disc
  • Water box
  • Air & water vent lines
Types of steam condensers:
  • Surface Condenser
  • Air Cooled Condenser
  • Jet Type Condenser
Types of surface condensers
  • Down flow type
  • Central flow type
  • Inverted flow type
  • Regenerative type
  • Evaporative type
Design considerations of surface steam condensers
Design code XEI-IX
  • Quality & Quantity of steam to be condensed
  • Exhaust steam pressure and temperatures
  • Steam velocity
  • Quantity & quality of cooling water
  • Operating pressure and temperature of cooling water
  • Fouling factor
  • Corrosion allowance
Effects of air leakage in condenser:
Lower Thermal Efficiency: The leaked air in the condenser results in increased back pressure on the turbine this means there is loss of heat drop consequently thermal efficiency of plant will decrease.
Increased Requirement of Cooling Water: The leaked air in the condenser lowers the partial pressure of steam due to this, saturation temperature of steam lowers and latent heat increases. So it requires more cooling water to condense more latent heat steam.
Reduced Heat Transfer: Due to poor conductivity of air heat transfer is poor.
Corrosion: The presence of air in the condenser increases the corrosion rate.
Functions of rapture disc & vacuum breaker valves in surface condensers:
Rapture disc is used to release the high pressure from steam condenser during excess pressure in condenser. Excess pressure may be due to cooling water pump failure or vacuum breaker valve failure etc. Rapture disc is thin steel foil designed to with stand condenser operating pressure, it raptures at high condenser pressure.
Vacuum breaker valve is used to bring down the turbine speed quickly to zero in case of emergency trip of turbine. Valve can be manually or auto opened.
Vacuum:
Vacuum is a sub-atmospheric pressure. It is measured pressure depression below the atmospheric. The condensation of steam in closed vessel produces a partial vacuum by reason of the great reduction in the volume of the low pressure steam or vapour. The back pressure on the steam turbine can be lowered from 1.013 to 0.1bar abs.
Reason for vacuum creation in condensers:
Condenser is mainly used to convert the low pressure steam at the end of the turbine to liquid so that the process is continued. As the pressure in the last phase of turbine is very low so the pressure in the condenser must be lower than that so that the low pressure steam can flow to condenser and get liquefied.
Generally vacuum pumps or ejectors are used to create vacuum in the condenser. Specific volume of water is much lower than the steam. Hence when the condensing process happens, volume of steam reduces and basic vacuum is created.
As liquids takes up less volume than gases whenever a steam is liquefied..there is a huge pressure drop as the drastic decrease in volume of liquids. The volume change takes place in the multiples of thousand at a certain pressure from the original volume of the gas.
Effect of under/low vacuum:
  • Lesser work done by Turbine & hence lesser power output
  • Higher steam consumption
  • Higher exhaust steam temperature
Effect of over/higher vacuum:
  • It causes sub-cooling effect where hot well temperature reduces more than design which required to be added in boiler leads to heat loss.
  • Erosion of last stage LP blades due to lower exhaust steam temperature


Vacuum & Condenser efficiency:

It is the ratio of actual vacuum to the maximum obtainable vacuum.

Vacuum efficiency in % =Actual vacuum X 100 / (Atmospheric pressure or barometric pressure-Absolute pressure)

Condenser efficiency =Difference in cooling water inlet & outlet temperatures X 100/(Vacuum temperature-condenser Inlet temperature of cooling water)
Condenser efficiency = (T2 - T1) X 100/(T3 - T1)
T2: Condenser outlet cooling water temperature,
T1: Condenser inlet cooling water temperature,
T3: Temperature corresponding to the vacuum or absolute pressure in the condenser.
Let us have glance over following calculations to for more clear understanding of above script
Example:1
A down flow type surface condenser has vacuum -0.92 kg/cm2 condenses 100 TPH steam at cooling water inlet and outlet temperatures 27 °C and 37 °C respectively, calculate the condenser efficiency.
Given that,
T1 = 27 °C, T2= 37 °C
T3 at vacuum -0.87 kg/cm2 is 48 °C
We have,
Condenser efficiency = (T2 - T1)/(T3 – T1)
                                      = (37 - 27) X 100/(48-27) =47.61%
Example-2:
Exhaust steam from condenser enters at 42 °C, if the vacuum gauge of condenser reads -0.89 kg/cm2, find the vacuum efficiency.
Given that,
Condenser pressure =-0.89 kg/cm2
Exhaust steam temperature = 42 °C
From steam tables, partial pressure of steam at exhaust temperature Ps = 0.084 kg/cm2
Maximum obtainable vacuum by considering atmospheric pressure as 1.033 kg/cm2
 = 1.033 - 0.084 = 0.95 kg/cm2
Vacuum efficiency = (Actual vacuum in condenser X 100)/Max. Obtainable vacuum.
                                 = 0.89 X 100/0.95
                                 = 93.6%
Example-3:
The volume of condenser which contains 0.162 kg of air with steam is 4.2 m3.Temperature in the condenser is 42 deg C and there is some water in the condenser. Determine the pressure in the condenser. Take R for air=287/joules/kg K
Given that,
Mass of air Ma =0.162 kg
Volume of air =V=4.2 M3
T=42+273=315 K
We have relation, PaVa=MaRT
Pa X 4.2=0.162 X 287 X 315
Pa=(0.162 X 287 X 315) X 10-5/4.2
Pa=0.035 bar
Partial pressure of water vapour at condenser temperature 42 deg c, Ps=0.08 bar
Pressure in the condenser = Pa+Ps=0.035+0.08 =0.115 bar
Gauge pressure =1.03-0.115 = -0.915 Bar
Example-4:
The air leakage into the steam condenser is 0.721 kg/min.The vacuum near the outlet of ejector is 690 mm of Hg when the barometer reads 760 mm of Hg & temp.at this point is 20 deg c..Calculate the mass of steam condensed.
Solution:
Pressure in the condenser =760-690 =70 mm of Hg
Convert into bar =70 X 0.001333 =0.0931 bar
Partial pressure of steam at 20 deg C =0.022 bar
So partial pressure of air Pa=0.0931-0.022=0.0713 bar
Mass of air leakage =Ma =0.721 kg/min
V = Ma X R X T/Pa
V = 0.721 X 287 X (273+20)/(0.0713 X 105)
V=8.5 M3/min
From the Dalton’s law of partial pressure, volume of the steam is same as air = 8.5 M3/min
Ms =Volume of steam/Specific volume of steam at 0.022 bar
Ms=8.5/62.5 =0.136 kg/min

Example-5:
A down flow type surface condenser is designed to handle 110 TPH of steam, the steam enters the condenser at 0.12 kg/cm2 absolute pressure and 0.9 dryness fraction. Condensate leaves at 45 °C, calculate the quantity of cooling water required, condenser inlet and outlet cooling water temperatures are 29 °C and 37 °C respectively.
Given that,
Mass of exhaust steam Ms = 110 TPH
Condenser pressure = 0.12 kg/cm2a
Dryness fraction x = 0.9
Cooling water condenser inlet temperature T1 = 29 °C
Cooling water condenser outlet temperature T2 = 37 °C
Condensate leaves at temperature Tc = 45 °C
We have,
Latent heat and saturation temperature of steam at exhaust pressure are
Hfg = 569.54 kcal/kg and T3 =49 °C
Mw = (Ms X (hfg X dryness fraction(x) + Cpw (T3 - Tc)))/(Cpw X (T2 - T1))
Mw = 110 X ((569.54 X 0.9) + 1 X (49 - 45))/(1 X (37-29))

        Mass of cooling water Mw = 7048.55 M3/hr

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Turbine oil and transformer oil standard testing parameters


                        BUY


PMG, EXCITATION, AVR & Power generation phenomenon in Generators



PMG:

The PMG (Permanent Magnet Generator) is a system which is used for secondary exciting. The PMG provides stable and reliable electric energy for AVR regardless the generator’s terminal voltage. The generator with PMG excitation system can provide 300% rated current during short-circuit, which occurs for 5–10 seconds.

The most common function of a diode is to allow an electric current to pass in one direction (called the diode’s forward direction), while blocking it in the opposite direction (the reverse direction). As such, the diode can be viewed as an electronic version of a check valve. This unidirectional behavior is called rectification, and is used to convert alternating current (AC) to direct current (DC).

EXCITER & EXCITATION:

DC supply is required to give to the field winding of a generator. This DC supply is obtained from various sources. Supply of DC power to the field is called excitation. There are two types of excitation.

• Separately excited generator
• Self-excited generator

In a separately excited generator, DC supply to the generator field is made available from a separate source which has no connection with the generator’s own generated supply. This type of generator is not used in the power plants. 

In a self-excited generator, DC supply to the field is temporarily given from the other source. Once the voltage is built up in the generator, this source is changed into the generator’s own generating supply. In this system, field supply is obtained either from an excitation transformer or from an exciter mounted on the generator shaft.

Brush less excitation system:
In this system, a small generator, called exciter, is mounted on the generator shaft. Exciter generator arrangement may be with brush-like static excitation system or brushless. In this arrangement, exciter generator is used which is a small generator having rotating coil and stationary field. This arrangement makes the excitation system brushless. No brush is required to feed the field current to the main generator. 

In exciter field of the exciter generator is stationary and the coil is rotating. Voltage generated in the rotating coil is rectified through a set of rotating diode bridge. Rotating diodes are mounted on an insulated base. Rectified output of this rotating diode bridge is connected to the field winding of the main generator (rotating) through cable which passes through drill way made in the shaft of generator. Supply to the stationary field of the exciter generator is obtained from an automatic voltage regulator (AVR). A separate source or a permanent magnet generator (PMG) is used for getting power supply for AVR. 

Power plant equipents efficiency calculation

AUTOMATIC VOLTAGE REGULATOR (AVR):

AVR system is used to control the generator out put voltage, irrespective of any load on the generator. By raising or lowering the field current (excitation), the output voltage of the generator can be raised or lowered respectively. Raising or lowering of field current is done with the help of an AVR. When load on a generator increases, its output voltage drops. By raising the field current, voltage can be raised to the normal level. Like this when, the load on generator reduces, the voltage of generator increases. In this case, field current is required to be reduced.

Other function of AVR are
  • It controls the power factor of generator.
  • It limits the stator current and rotor current
  • It also limits the load angle.
  • It detects failure of any diode.
Phenomenon of Power generation in Turbine & Generators:

Calculation of Power generation in Steam Turbines
Step-I -Start Up:
  • After reaching the rated pressure and temperature of steam, turbine will be given run command.
  • Turbine will speed up as per start up curve and reaches rated speed.
  • At the rated ideal speed, turbine will consume minimum steam to maintain only speed.
  • At rated speed of Turbine , alternator (4 pole) also will rotate with 1500 rpm.
  • At this speed PMG will generate AC three phase voltage.
  • This three phase AC voltage is made to fed to AVR.
  • In AVR, this AC voltage will convert into DC through rectifier and is again fed to AC exciter field, which is stationary.
  • AC voltage generated from rotating coil of the AC exciter is rectified through rotating diodes and this DC voltage is fed to field winding of main generator through cable which passes through drill way made in the shaft of generator.
Step-II- Load Raising:
  • Once Generator reaches 1500 rpm AVR is made ‘ON.’
  • After AVR is made ON, rated voltage of generator is bulid up at its terminals.
  • Then Generator breaker is closed to share the auxiliary load of the plant.
  • After closing the Generator breaker, the generator gets synchronized with DG.
  • After synchronizing DG is made “OFF” and STG will share home load (plant auxiliary load).
  • In order to share the extra load on turbine, power is to be pumped to external grid.
  • In order to raise the load, a load “rise” command is given to Wood word governor through DCS or through local panel.
  • This “rise” command for a particular load is calculated in terms of percentage of droop in Governor & based on this a reference speed will be generated. (For example for 20 MW,6300 RPM & 4% droop Turbine  has reference speed  =6300+6300 X 4% = 6552 RPM) 
  • This calculated reference speed signal will be go to HP valve for opening the HP valve
  • After opening the HP valve torque on the turbine rotor will increase (speed will not increase as turbine is connected with grid frequency).
  • This torque on the turbine rotor will transfer to reduction gear box (RGB) and also on generator rotor.
  • Due to this higher torque stress will produce on stator winding, which causes to increase of current on main generator, as voltage and speed are constant.
  • This high current and voltage are compared and MW signal will be generated
  • This rise and drop in current and voltage will be sensed by AVR through CT/PT situated at generator output bus bars, so AVR maintains rated voltage by giving more/less excitation to AC exciter. Thus the process continues.



















Thumb rules for power plant




BOILER:
  • Boiler heating surface (M2) = Boiler capacity in kg/hr/(17–18)..Ex: 115 TPH boiler will have heating surface = (115 X 1000/17 or 18) = 6390 to 6750 M2 (Appx.)......
  • Boiler flue gas ducting size (M2) = Boiler capacity in TPH/15.
  • No. of open tubes in steam drum for water recirculation = 30–31% of total no. of tubes present.
  • Deaerator steam venting capacity = Deaeration capacity X 0.1%.
  • Super heater safety valve relieving capacity at full open condition in TPH = Boiler MCR X 36–38%.......Ex: 125 TPH Boiler has SH safety valve of relieving capacity = (125 X 36/100) = 45 TPH.
  • Drum safety valve (1 no.) relieving capacity at full open condition in TPH = Boiler MCR X 46–48%.
  • All boiler safety valves (super heater and drum safety valves) relieving capacity at full open condition= Boiler MCR X 125–130%.
  • Safety valves pop up pressure = Operating pressure X 106–107%.Ex: A boiler operating pressure of 110 kg/cm2 has safety valve set at 110 X 106/100 =116.6 kg/cm2.
  • Boiler start up vent steam blow capacity 30–35% of boiler MCR on full open condition.
  • Boiler CBD water flow is 0.8 to 2% of steam generating capacity of the boiler.
  • Drum man hole door size 410 mm X 310 mm (Elliptical).
  • Boiler drum hold up capacity is 2–4 minutes at MCR operation.
  • Feed water velocity in Economiser coils 0.6 to 1 meter/sec.
  • Pressure drop in Economiser coils 0.5 to 1 kg/cm2.
  • Flue gas Pressure drop in ESP 25 to 30 mmwc.
  • A travelling grate Boiler ID fans motor rated capacity in KW = Boiler capacity TPH X 200%.....Ex: A boiler of capacity 75 TPH requires ID fan motor of rated KW = 75 X 200/100 = 150 KW each
  • A travelling grate Boiler ID fans (2 Nos) capacity (m3/sec.) with 25% extra margin = Boiler Capacity(TPH) X 95%.....Ex: A 100 TPH boiler has two ID fans of each capacity =100 X 95/(100 X 2) = 47.5 m3/sec.
  • Mass of flue gas generated = Mass of air per kg of fuel to be burned + 1.
  • Boiler fans power consumption = Total plant auxiliary consumption X 35–38%.
  • Boiler feed pumps power consumption = Total plant auxiliary consumption X 35–38%.
  • Turbine auxiliary power consumption = Total plant auxiliary consumption X 10–12%.
  • Fuel handling power consumption = Total plant auxiliary consumption X 4%.
  • For every 1% increase in bagasse moisture, boiler efficiency reduces by 0.27% and vice versa.
  • For every 5% increase in excess air for bagasse, boiler efficiency decreases by 0.18% and vice versa.
  • For every 100 kcal/kg increase in bagasse GCV, boiler efficiency increases by 1.2% and vice versa.
  • For every 0.5% increase of Hydrogen in bagasse, boiler efficiency decreases by 0.8–1% and vice versa.
  • For every 10 °C increase in flue gas temperature, boiler efficiency decreases by 0.45% and vice versa.
  • For every 100 kcal/kg increase in GCV of coal, boiler (TG) efficiency increases by 0.36% and vice versa.
  • Boiler peak load = Boiler MCR X 110%.
  • Minimum possible duration of boiler peak load is 30 minutes/shift.
  • Minimum stable operating load on the boiler is around 30% of boiler MCR.
  • Total dissolved solids = Conductivity X 06.

TURBINE AND AUXILIARIES:
  • Control oil pump capacity = AOP/MOP capacity X 10%.
  • Emergency oil pump capacity = AOP/MOP capacity X 25%.
  • Lube oil required for gear box = Total lube oil circulating X 60–65%.
  • Lube oil required for generator = Total lube oil circulating X 8–10%.
  • Lube oil required for turbine = Total lube oil circulating X 20–25%.
  • Lube oil outlet temperature = Lube oil inlet temperature + 15–20 °C.
  • Cooling tower evaporation loss = Turbine exhaust steam to condenser X 80–90%.


MAINTENANCE:
  • Minimum allowable bearing clearance in mm = 0.00185 X bearing ID
  • Maximum allowable bearing clearance in mm = 0.00254 X bearing ID.
  • Bearing grease top up quantity = 0.05 X b X d, b = bearing width in mm, d = bearing OD in mm.
  • Hub size = 2 X Shaft diameter.
  • Shaft Key size, width = (d/4) + 2, thickness = d/6, (d = diameter of shaft).
  • Minimum span for pipe line supporting in meter = (7√d)/3, where d = pipe OD in inches.
  • Threading length of half threaded bolt = 2d + 6 mm (if bolt length l <150 mm) and 2d + 12 mm (if bolt length l >150 mm).
  • Spanner size = Bolt major diameter (mm) X 1.5.
  • Nut thickness = 0.9 X d, d = nut size.
  • Bolt head thickness = 0.8 X d, d = major diameter of bolt.
  • Washer Internal diameter = D + 1…mm.
  • Washer outer diameter = 2D + 3……mm.
  • Washer thickness = D/8, where D is OD of washer.
  • Diameter of bolt head across the flat ends = 1.5 X d + 3 mm.
  • Welding current required for welding (Amps) = Welding rod size (mm) X 40 +/- 20.
  • Pipe weight/foot = (dt − t2) X 4.85...kg/foot, (pipe OD in inches & t is thickness of pipe in inch).
  • Pipe line spacing = Flange size of maximum diameter pipe + Smallest pipe size + Insulation thickness + 25 mm.
  • Preheating of steel is done if %C + %Mn/4 is >0.58.
  • Boiler platform loading capacity 500 kg/m2.
  • Boiler fire man floor platform loading capacity 1000 kg/m2.
  • Brinnel hardness number (BHN) = Rockwell hardness number X 10.8.
  • Bearing, grease or lip seals have a design life of less than 2000 hours. In a constantly running pump this would be only 83 days.
FUEL HANDLING:
  • Tail pulley, bend pulley and take up pulley Outer diameter = Head pulley OD X 80%.
  • Snub pulley OD = Head pulley OD X 60%.
  • PCS (Pull Chord Switch) are placed at every 15 meters along the length of conveyor.
  • BSS (Belt Sway Switch) are placed at every 30 meter along the length of conveyor.
  • Carrying and return self aligning transoms are placed at every 20 meters along the length of the belt.
  • Horizontal chain conveyor motor capacity = Chain span X Fuel handling capacity / 80
Example: A chain conveyor of capacity 100 TPH & having centre to center distance 30 meters requires motor of capacity 100 X 30 / 80 =37.5 KW to drive the conveyor safely
PUMPS:
  • Pump shutoff head = Design head X 1.07.
  • Pump efficiency with cold water is less than pump efficiency with hot water
  • Safe operating speed of boiler feed pumps is 55–60% of rated speed.
  • Boiler feed pumps suction strainer pressure drop should be 0.04 to 0.06 kg/cm2.
  • The pumps best efficiency point (B.E.P.) is between 80% and 85% of the shut off head.
  • A double suction pump can run with less N.P.S.H. or at faster speed without cavitating.
  • Multistage pumps reduce efficiency 2% to 4%.
  • 1% capacity of pump will reduce on every 0.025 mm increase in wear ring clearance.
  • Suction piping should be at least one size larger than the suction flange of the pump.
  • Pumps piped in series must have the same capacity (impeller width and speed).
  • Pumps piped in parallel must have the same head (impeller diameter and speed). 
  • A centrifugal pump can handle 0.5% air by volume. At 6% it will probably become air bound and stop pumping. Cavitation can occur with any amount of air.
  • A Vortex pump is 10% to 15% less efficient than a comparable size end suction centrifugal pump.
  • There should be at least 10 diameters of pipe between the suction of the pump and the first elbow.
ELECTRICAL:
  • Rating current of motor = 1.36 X hp or 1.79 3 KW.
  • Starting current of a single phase motor (1 to 10 HP) = 3 X Motor full load current.
  • Starting current of a three phase motor (up to 15 HP) = 2 X Motor full load current.
  • Starting current of a three phase motor (>15 HP) = 1.5 X Motor full load current.
  • Current carrying capacity of copper cable: 2 amps/mm2.
  • Earthling resistance for single pit is <2 ohm.
  • Voltage between neutral and earth <2 V.
  • Resistance between neutral and earth <1 ohm.
Motor body earthing strip size:
  • 85 SWG GI Wire for motors <5.5 KW.
  • 25 X 6 mm GI Strip for motors 5.5 to 22 KW and Lighting and control panels.
  • 40 X 6 mm GI Strip for motors 5.5 to 22 KW.
  • 50 X 6 mm GI Strip for motors >55 KW and D.G and Exciter Panel.
  • Motor insulation resistance = (20 X voltage)/(1000 + 2 X motor KW).
  • Single phase motor draws 7 amps current per HP.
  • Three phase motor draws 1.25 to 1.36 amps current per HP.
  • No load current of three phase motor is 30 to 40% of full load current of motor.
  • Submersible pump takes 0.4 KWH of extra energy at 1 meter drop of Water.
  • Creepage Distance 5 18 to 22 mm/KV for moderate polluted air and 25 to 30 mm/KV for highly polluted air.
  • Minimum Bending Radius for LT Power Cable is 12 X diameter of Cable.
  • Minimum Bending Radius for HT Power Cable is 20 X diameter of Cable.
  • Minimum Bending Radius for Control Cable is 10 X diameter of Cable.
  • Insulation Resistance Value for Panel = 2 X KV rating of the panel.
  • Test Voltage (AC for Meggering = (2 X Name Plate Voltage) + 1000.
  • Test Voltage (DC for Meggering = (2 X Name Plate Voltage).
  • Current Rating of Transformer = KVA X 1.4.
  • No load current of Transformer = <2% of Transformer rated current.
  • There are 4 Nos. of earth pits per transformer (2 No. for body and 2 No. for neutral earthing).
  • Diesel generator set produces 3 to 3.5 KWH/liter of diesel.
  • DG less than or equal to 1000 KVA must be in a canopy.
  • DG greater than 1000 KVA can either be in a canopy or skid mounted in an acoustically treated room.
  • DG fuel storage tanks should be a maximum of 990 Litter. Storage tanks above this level will trigger more stringent explosion protection provision.
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Understanding the specific terms for Power plants performance analysis





It is very must to understand the basic fundas of specific terms used in power plants.

The following terms very frequently used in power plant calculations

1-SFR:It is steam to fuel ratio, it is the amount of steam generated on burning or oxidation of 1 MT of fuel. 

SFR =Steam generated / Fuel consumed
Note:If steam generated is taken in MT, then take fuel conssumed also in MT  , so the SFR is unitless

SFR depends on 
  • Type of the fuel & its GCV
  • Type of the Boiler & its efficiency
If the fuel GCV & Boilr efficiency are high,then SFR value will be more and vice versa


2-SSC: Spcific steam consumption, it is the amount of steam required to generate 1 Kwh or 1Mwh of power.

SSC = Steam consumption / Power generated

Note: If steam consumption taken is in MT,then power generation should be in MW.And if steam consumption taken is in Kg,then power generation should be in Kw.

SSC depends on the type of steam Turbine & its operating parameters.

  • If the turbine has lesser number or no any extractions or bleeding steam, then the SSC value of that particular turbine will be less

  • If the steam pressure and temperature at the Turbine inlet are more than the SSC value is less


3-SFC:It is the amount of fuel consumed to generate one Kwh of power

SFC = Fuel consumed in MT or Kg / Power generated in Mwh or Kwh

SFC is also give as,

SFC = SSC / SFR

SFC is less for power plants which have,

  • Higher Boiler efficiency
  • Higher fuel GCV
  • Higher steam pressure & tempeatures
  • Condensing turbines 

4-PLF: Plant Load Factor, it is the ratio of average power generation to the plant capacity during that period. It is expressed in %.

PLF = (Average power generation X 100) / Plant capacity during particular period.

5-PCF: Plant Capacity Factor is the ratio of average power generation to the plant installed capacity. It is expressed in %.

PCF = (Average power generation X 100)/Plant installed capacity.

6-PAF:Plant Availability Factor ,it is the ratio of total time in hours utilized for power generation to the total available hours for power generation. It is expressed in %.

PAF = (Total hours utilized for power generation X100)/Total available hours

Basics of Thermodynamics

7-Demand Factor:It is the ratio of maximum demand to the total connected load. It is always less than unity. Lower the demand factor, the less system capacity required to serve the connected load.

8-Diversity Factor: It is  the ratio of total connected load to the maximum demand. It is always greater than unity.

Let us solve follwoing examples to be more clear on above specific terms.

Example-1:A Coal fired Boiler of capacity 75 TPH, generates 1680 MT of steam in a day at SFR 2.2, calculate the fuel consumed

SFR = Steam generation / Fuel consumed
Fuel consumed = 1680/2.2
Fuel consumed = 763.63 MT

Example-2:A cogneration based 25 MW steam Turbine has specific steam consumption (SSC) 5.5 MT, calculate the steam flow per hour

SSC = Steam consumed / Power generation
Steam consumed = 5.5 X 25 =137.5 MT/hour =137.5 TPH

Example-3: A Therml power plant generates 2000 MW power in a consumes 1230 MT coal and generates 8000 MT of steam, calculate SFR, SSC & SFC of the thermal power plant

SFR =Steam generated / Fuel consumed
SFR = 8000 / 1230 = 6.5

SSC = Steam consumed / Power generation
SSC = 8000 / 2000 =4.0 MT of steam / MW of power

SFC = Fuel consumed in MT or Kg / Power generated in Mwh or Kwh
SFC = 1230 / 2000 = 0.615 kg of coal / kwh of power generated
or 
SFC = SSC / SFR = 4.0 / 6.5 =0.615 kg of coal / kwh of power generated

Example-4:Power generation of 70 MW power plant is restricted to 45 MW due to fuel constraint, calculate the PLF and PCF if average generation of the plant in day is 42.5 MWH.

Plant load factor (PLF) = (Average power generation in a day) X 100/(Plant capacity on particular period)
                                      =(42.5 X 100/45) = 94.4%
Plant capacity factor (PCF) = (Average power generation in a day) X100/(Plant installed capacity)
                                             = (42.5 X 100/70) =60.7%

Example-5:A power station has a connected load of 50 MW, the maximum demand at the station is 25 MW. Find the demand factor.
Demand factor (DF) = Maximum demand/Connected load
                                  = 25/50 =0.5

Example-6: A power plant runs 365 days in a year, but due to major breakdown in Turbine, plant taken sshutdown for 2days, calculate the plant availability factor

PAF = (Total hours utilized for power generation X100)/Total available hours

PAF = (365-2) X 24 X 100 / (365 X 24)
PAF = 99.45%

PAF can also be calculated by considering the days

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