section a.6 steam and water cycle equipment
DESCRIPTION
ghTRANSCRIPT
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
Page 1 of 19
6.0 STEAM AND WATER CYCLE EQUIPMENT 6.1 General 6.1.1 The steam water and cycle equipment design shall be as per this section
including data sheets. 6.2 Surface Condenser and Accessories 6.2.1 The selected condenser together with the condenser cooling water system
shall be such that the condenser pressure, corresponding to a sustained HP-IP-LP bypass operation (nearly fully open) and turbine operation at house load at maximum cooling water inlet temperature to condenser, is less than the turbine alarm value for the high condenser back pressure by a reasonable limit.
6.2.2 The contractor shall take into account the following aspects in respect of
condenser design: (a) Water box shall be designed for integrity against maximum circulating
water transients i.e. design of circulating water system side to the circulating water pump shut-off head to next higher 0.5 kg/cm2 plus an allowance for water hammer surge, if required as verified by vendors calculation. The calculation shall be submitted for review. The water box test pressure shall be at least 1.5 times the design pressure
(b) The condenser shall be capable for part load operation of the STG unit with one half of the condenser out of service. This operation however will be for short duration only.
6.2.3 The location and design of steam and water dumps to the condenser shall
be in accordance with ASME Standard TDP-1, Part-1. 6.2.4 The condenser design shall provide for adequate bowing or sloping of
tubes to assure complete drainage of the tubes. 6.2.5 A vacuum grid shall be fitted to ensure that an average reading can be
obtained and the grid shall be fitted 300 mm from the edge of condenser tube bundle nearest the turbine exhaust for measurement of condenser vacuum.
6.2.7 Each water box shall be provided with drain valves of adequate size at the
bottom to enable the front and rear water box and tubes to be emptied of water in not more than 30 minutes.
6.2.8 Access manholes of adequate size shall be provided, one in each of
the hotwell sections. Hotwell connections to suction of condensate
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
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extraction pumps shall have anti-vortex baffling and the material of screen mesh shall be of stainless steel type 304.
6.2.9 A suitable means of access shall be provided inside the condenser to
permit inspection and cleaning of confined areas. An access manhole of 600 mm x 600 mm size minimum shall be provided on the shell above tubes.
6.3 CONDENSER AIR EVACUATION EQUIPMENT 6.3.1 2 X 100% duty mechanical vacuum pumps and accessories shall be
used to create vacuum by removing air and non-condensable gases from steam condenser during plant start-up and operation. The pumps shall be single stage liquid ring with an air ejector or two-stage liquid ring type. In case of a two stage pump both the stages shall be mounted on a common shaft.
6.3.2 The unit shall require no internal lubrication and shall not be damaged
by water vapour, entrained droplets or slugs of water. 6.3.3 Provision shall be made in the design of the equipment to prevent loss
of vacuum by flow of atmospheric air back into the condenser upon shutdown of the pump.
6.3.4 The control system shall be such that the entire operation from hogging
through holding can be carried out automatically. 6.4 CONDENSATE EXTRACTION PUMPS AND ACCESSORIES 6.4.1 For maximum availability between planned maintenance periods,
components of pump shall not be made of materials which are degradable and/or which will wear and need replacing within 40,000 hours with the exception of mechanical shaft seal materials, which shall be capable of operating for not less than 15,000 hours.
6.4.2 Each pump set shall:
(a) Be capable of supplying the starting requirements of the plant. (b) Satisfactorily accommodate steady and transient loadings imposed
by the main pipe work.
6.4.3 The pump characteristic curve test tolerances shall be limited to : Plus (%) Minus (%) (a) Flow at guarantee point 0 0 (b) Head at guarantee point 3 0
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
Page 3 of 19
(c) Efficiency at guarantee point Unlimited 0 (d) Shut-off head 5 0 These tolerances shall be the permissible variations between the
conditions as proposed initially by Bidder and the design parameters demonstrated during the acceptance tests.
6.4.4 The pump motor rating shall not be less than larger of the following :
(a) Sufficient to drive the pump through the entire range of runout flow to shut-off conditions.
(b) 110% of pump design point rating.
6.4.5 The construction shall be such as to allow removal of pump shaft and
impeller without disturbing the can. 6.4.6 The suction side vent of each cannister shall be individually connected
to condenser. Discharge side vent of each condensate extraction pump shall have its own solenoid valve operated, together with break down orifice and be connected individually to condenser.
6.4.7 The initial sealing water for the condensate extraction pumps shall be
from hotwell make-up system and during normal operation from condensate extraction pump discharge. Transfer from one sealing water source to another shall be automatic.
6.5 DEAERATING FEED WATER HEATER 6.5.1 The deaerator shall be capable of satisfactory operation under normal
operation, condition of turbine trip and bypass operation (full open) and lowest condenser pressure. Minimum condenser pressure shall not affect deaerator performance in any manner.
6.5.2 In case of spray-tray type with direct-contact vent condenser parallel
flow of steam and water is not desirable. Tray supports shall be rigid enough to withstand severe vibrations that would be caused due to water hammering during start-up and full load throw-off conditions. The sprayer shall be a spring controlled spray valve (variable flow area) which ensures fine atomisation of condensate at all loads. The sprayer device shall provide a self regulated system in which disc/piston opening adopts automatically to the changing hydraulic loads.
6.5.3 The spray type deaerator shall be Stork type or proven equivalent
construction which combines in one vessel the functions of deaerator, pre-heater, vent condenser and feed water storage tank. The design shall incorporate suitable spray valves of disc type or equivalent, splash
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
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plates, baffles, grids, etc. which ensures fine atomisation of incoming condensate, rapid heating up by steam and higher residence time. The rake supplying heating steam shall be suitably supported to prevent vibration. A separate heating steam rake to supply heating steam during start-up shall be provided.
6.5.4 The outlet pipes from the feed water storage tank shall be provided with
a vortex breaker and project a minimum of 75 mm above the bottom of the storage tank.
6.5.5 The vent from the continuous blow down tank (CBDT) will also be led to
the deaerator. 6.5.6 The sprayer shall be designed to ensure fine atomisation of condensate
at all loads upto 110% of the design flow. 6.6 HRSG FEED PUMPS 6.6.1 The requirements indicated here are applicable for all the HRSG feed
water pumps in steam and water circuit. 6.6.2 In designing the system, attention shall be paid to the NPSH
requirements of the pumps during normal operation and transients.. 6.6.3 Each HRSG feed pump set as a whole shall be capable of withstanding
the reverse rotational speeds which would result from non-return valve failure under the most severe condition. CONTRACTOR shall provide reverse rotation detection system to close discharge valve on detection of same.
6.6.4 Pump characteristic curve test tolerances shall be limited to : Plus(%) Minus(%) (a) Flow at guarantee point 0 0 (b) Head at guarantee point 3 0 (c) Efficiency at guarantee point Unlimited 0 (d) Shut-off head 5 0 These tolerances shall be the permissible variations between the
conditions as initially proposed by the Bidder and the design parameters demonstrated during acceptance tests.
6.6.5 Pump with high suction specific speed not proven in practice is not
acceptable. The impeller shall be designed for minimum 40,000 hours operation.
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
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6.6.6 The pump motor rating shall not be less than the larger of the following
:
(a) Sufficient to drive the pump through the entire range of run-out flow to shut-off conditions.
(b) 110% of pump design point rating. 6.6.7 All bearings shall be provided with a forced lubrication from a common
oil system for HP / IP or HP feed pumps. The thrust bearings shall be of tilting pad type. Also the design of lubricating oil system should take into account the oil requirements of the motor. Bearings shall be easily accessible without disturbing the pump. Each bearing housing shall have a drain plug. The balance drum leak-off shall be internal to pump
6.6.8 Each HRSG feed pump set shall be provided with flexible couplings of approved type between the motor and pumps and hydraulic coupling.
6.6.9 A forced lubricating oil system for HRSG HP / IP or HP feed pumps and motor with necessary instrumentation and control shall be supplied. The lubrication system shall include, but not necessarily be limited to, a shaft driven oil pump, a spare full capacity electric motor driven oil pump, all piping, valves, return flow sight gauges, relief valves, oil coolers, pressure and temperature switches, duplex or two simplex filters, pressure gauges, flow control devices, oil level indicators, thermometers including return oil thermometer for each bearing and on oil reservoir.
6.6.10 Mechanical Seals (a) The mechanical seals shall have a life expectancy of 15,000 hours.
(b) A cooling jacket shall be incorporated in the gland design. This
shall consist of a water circulation ring, magnetic filter and sealing water cooler. Auxiliary cooling water shall be used for the cooling and the system shall have a suitable filling, venting and draining arrangement.
6.6.11 Variable Speed Hydraulic Coupling, if applicable
(a) Bidder shall note that for steam and water cycle with HP
pressure as indicated in item 2.3.2 (a) of data sheets, hydraulic coupling shall be provided for the HP-IP pressure pumps.
(b) This shall be of Voith design or equivalent and shall be rated for
maximum duty of the main pump of the HP / IP or HP BFP set.
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
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The pump speed can be steplessly varied over a range 20% to 100% of pump rated speed
(c) The scoop tube shall be operated by a servo positioner which is
powered by the coupling lubricating oil system. A stepper motor shall interface with the servo positioner with a suitable linkage provided. A special requirement is the need for rapid starting and response to control signals. The coupling and its auxiliaries shall be designed to reduce inherent time lags to a minimum. The start-up time for the complete BFP set is to be not more than 15 seconds.
6.7 HP / IP / LP Bypass System 6.7.1 100% capacity HP/IP/LP bypass system shall be provided for each
HRSG to facilitate following, in case Bidder is offering dual pressure HRSGs, the HP/ LP bypass shall meet the requirements outlined here:
(a) Operation of the HRSGs when
(i) Load is either temporarily lost on the steam turbine generator or is rapidly reduced,
(ii) Steam turbine generator is tripped. (b) Rapid matching of steam and turbine metal temperatures
during start-up of the turbine. (b) Serving as a pressure relief system to reduce the risk of HRSG
safety valves lifting when rapid load reduction on the steam turbine generator occurs.
(c) Continuous operation of the steam turbine at part loads with
HRSG operating at 100% MCR condition.
6.7.2 Each pressure level of bypass station shall be designed for the maximum steam pressure, i.e. The safety valve set pressure in the respective section and sized for maximum steam capacity generated. In addition to the above, necessary margin for the condensate injection shall be considered. Each bypass station shall comprise a quick acting stop valve and a pressure control valve on steam line (operated by separate actuators), a desuperheater, a stop valve and a control valve on spray water injection line (operated by separate actuators), necessary instrumentation and control equipment, all necessary piping, valves and fittings. Bidder shall indicate the arrangement made for dumping the bypass steam into the condenser
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
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and the same shall be subject to Owner / Owners Representative approval.
6.7.3 The bypass control valves shall have the stroking time of not more than
3-4 seconds for fast opening and 10-15 seconds for normal stroking. The spray water system for temperature control shall be compatible with the HP bypass control valve requirements. They shall be provided with electro-hydraulic actuators. If the oil system is a self contained unit, it shall have 100% standby oil pump connected to main system with necessary valves for isolation and maintenance. Hydraulic accumulators shall be provided on the hydraulic system to ensure positive supply of oil to hydraulic actuators even when hydraulic oil pumps are not available. Accumulator shall be adequately sized to ensure supply for two complete stroking operation of all connected actuators. All control valves shall be of tight shut-off design and the actuators shall be designed for maximum shut-off differential pressure acting across the valve. Low noise trim shall be provided to limit the noise level to 85 dBA at a distance of 1.0 m from outline of valve at all operating conditions.
6.7.4 The HP-IP-LP bypass system shall rapidly shutdown upon detection of
low spray water pressure, high steam temperature downstream of desuperheating stations and high reheater / condenser pressures.
6.7.5 Special attention shall be paid to provision of warming up drains as close to
the bypass valves as possible in order to minimise thermal shock on bypass valves and upstream pipe work when bypass comes into operation.
6.7.6 The systems downstream of bypass valves shall be capable of withstanding
the thermal shock due to failure of spray water.
6.8 Excess Condensate Dump System 6.8.1 Excess condensate dump system shall dump the excess condensate in
condenser hotwell to the condensate storage tank through an excess condensate dump line downstream of condensate extraction pump discharge. The excess condensate dump line shall be provided with an excess condensate dump control valve sized for not less than 10 percent steam turbine VWO flow.
6.9 General Process Requirements for Control Valves 6.9.1 All control valves for entire contract shall be sized such that the valves are
controllable over entire operating regime viz. low load to full load. The control valves which require to be operated during cold, warm and hot start conditions shall also be controllable during this mode of operation. To meet the above requirements if CONTRACTOR provides more than one control
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
Page 8 of 19
valve, the controllable ranges of the control valves shall overlap to ensure bumpless transfer from one control valve to other. For other requirements of control valve refer relevant C&I sections.
6.10 General Requirements Of Auxiliary Coolers 6.10.1 All the auxiliary heat exchangers provided for the entire contract shall be
designed to meet the requirements of TEMA-R unless otherwise specifically mentioned.
6.11 General Requirements Of Centrifugal Pumps 6.11.1 All the centrifugal pumps for entire contract shall meet the requirements of
API 610 standard unless otherwise specifically mentioned.
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
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1.0 SURFACE CONDENSER & ACCESSORIES
1.1 Configuration - Condenser with axis perpendicular or
parallel to STG axis.
- Axial condenser with axis perpendicular
to STG.
- Side mounted axial condenser with each
half on either side of STG with axis
parallel to STG axis and interconnection
between hotwell shall be provided for
level balancing.
OR
- Bottom mounted condenser with axis
perpendicular to STG axis.
1.2 Type of condenser Two pass. Single shell with divided water
box to facilitate unit operation with one half
under maintenance for condenser with axis
perpendicular to STG axis or single shell type
for each side mounted condenser with axis
parallel to STG axis such that one side can be
isolated and unit run with only one side
mounted condenser in service.
1.3 Orientation of condenser tube axis Parallel or perpendicular to STG axis as per
item 1.1 above.
1.4 Quality of cooling water For analysis refer Project Information Section
B.
1.5 Design cooling water inlet temperature (CWIT) Same as cooling tower recooled water design
temperature after accounting for any heat gain
or loss.
1.6 Design margin on heat load at TG VWO, 0%
MU, Design CWIT
% 5
1.7 Steam bypass - Shall be designed for 100% HP-IP-LP
steam bypass operation continuously
- Condenser back pressure shall not exceed
0.15 kg/cm2 (a) at max. condenser cooling
water temperature at above conditions
1.8 Hotwell storage capacity normal level to low
level (150 mm above bottom of hotwell)
3 minutes of turbine VWO flow, 1% MU,
design CWIT
1.9 Hotwell water level - Very high water level in condenser shall
be atleast 150 mm lower than the tip of
longest blade of low pressure turbine.
- Turbine trip on very high water level.
1.10 Tube cleanliness factor % 90
1.11 Cooling water velocity in condenser tube m/s Not to exceed 2.0 m/s.
1.12 Oxygen in condensate at hotwell outlet with
3% make-up from 30% TG MCR to TGVWO
cc/litre Not to exceed 0.03
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380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
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1.13 Water box design pressure Shall be equal to the circulating water pump
shut-off head, rounded off to next higher 0.5
kg/sq.cm plus an allowance for water hammer/
surge, if required.
1.14 Shell side design pressure Turbine rupture disc pressure & full vacuum
1.15 Shell side design temperature Turbine exhaust hood temperature high trip
setting
1.16 Tube gauge in air cooling zone BWG 22
1.17 Tube gauge in condensing zone BWG 18
1.18 Minimum tube sheet thickness mm 40
1.19 Minimum tube support plate thickness mm 12
1.20 Minimum steam impingement baffle thickness mm 10
1.21 Water box lining 3mm fibre reinforced epoxy
1.22 Tube sheet coating on CW side Epoxy coating
1.23 Type of protection for tubes against
impingement of steam from
(a) Main turbine exhaust Higher thickness tubes / dummy tubes
(b) HP / IP / LP bypass exhaust Baffles / steam throw-off device (as required)
(c) Drains Baffles
1.24 Type of tube sheet to shell joint Welded
1.25 Type of condenser neck to steam turbine
exhaust joint
Welded
1.26 Lateral movement of condenser compensated
by
Spring supports
1.27 Corrosion allowance on ferrous parts mm 3.2
1.28 Materials Of Construction
1.28.1 Condenser shell, hotwell and condenser neck Carbon steel to SA 516 Gr. 70 or equivalent
1.28.2 Water box Carbon steel to SA 516 Gr. 70 or equivalent
1.28.3 Structural parts Carbon steel
1.28.4 Tube sheets Carbon steel to SA 516 Gr.70 or equivalent
1.28.5 Tubes in condensing section Aluminium brass UNS C60800
1.28.6 Tubes in air cooling section 90-10 Cupro nickel C70600
1.28.7 Tube support plates Carbon steel to SA 516 Gr. 70 or equivalent
1.28.8 Gaskets on water side Neoprene
1.28.9 Bolts ASTM A. 193-B7 or equivalent
1.28.10 Nuts ASTM A. 194-2H or equivalent
1.28.11 Dummy tubes / rods Two rows of SS 304
1.29 Accessories
Conductivity Measurement Provision cathodic
protection
Required
1.30 Codes And Standards
1.30.1 Heat Exchange Institute Standards for Steam
Surface Condensers
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
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1.30.2 American Society of Mechanical Engineers
1.30.3 ASME Performance Test Code for Condensers
1.30.4 American Society for Testing Materials
1.30.5 Other established material or international
codes and standards equal or superior to the
above listed standards.
2.0 CONDENSER AIR EVACUATION EQPT.
& ACCESSORIES
2.1 Number Two x 100% capacity; During normal
operation one pump will be in operation
2.2 Duty Continuous
2.3 Vapour to be handled Mixture of air, steam and non-condensable
gases
2.4 HEI standard pressure and temperature
conditions for air suction
0.034 kg/sq.cm (a) and 21.1 deg.C
2.5 Capacity
2.5.1 Capacity of pump Shall be not less than 120 percent the capacity
obtained from HEI standards
2.5.2 Capacity of pump during hogging Shall be able to maintain vacuum upto 0.35
kg/sq.cm(a) within 20 minutes with both the
vacuum pumps in operation, from atmosphere
pressure.
2.6 Source of sealing water Condensate
2.7 Type of coupling Flexible coupling
2.8 Acceptable noise level at all operating
conditions
dBA Not to exceed 85 at a distance of 1.0m from
the outline of equipment
2.9 Allowable vibration level at all operating
conditions
mm/sec 7 peak
2.10 Material of Construction
2.10.1 Vacuum pumps
(a) Casing Cast iron
(b) Shaft Carbon steel EN-8
(c) Impeller Nodular iron
(d) Shaft sleeves Nodular iron
2.10.2 Seal Water Recirculation Pumps (if
required)
(a) Casing Cast iron
(b) Shaft Carbon Steel EN-8
(c) Impeller Nodular iron
2.10.3 Heat Exchangers
(a) Shell Carbon steel
(b) Tubes Stainless Steel
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380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
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(c) Tube sheet Carbon steel with epoxy coating as required
2.11 Codes and Standards
2.11.1 HEI Standards for Steam Surface Condenser
2.11.2 HEI Standards - Performance Standard for
Liquid ring vacuum pumps
2.11.3 ASME Performance Test Code
2.11.4 TEMA Standards
2.11.5 Hydraulic Institute Standards
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
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1.0 CONDENSATE EXTRACTION PUMPS
& ACCESSORIES
1.1 Number of pumps 2 x 100%, One Working and One Standby
1.2 Operation Continuous at any point between minimum
flow to runout flow
1.3 Pump type Vertical cannister type
1.4 Design capacity per pump Total combined flow of normally working
pumps shall be 110 % condensate flow at
turbine VWO at maximum cooling water inlet
temp. or 105% condensate flow requirements
at design inlet condenser cooling water
temperature during a 100% HP-IP-LP bypass
operation or any other condition causing
maximum condensate flow to be a maximum
and 1% make-up plus sealing water flow to
valves plus any other spray water requirement,
rounded off to nearest higher 5 cubic metre per
hour
1.5 Minimum flow per pump Not less than twenty five (25) percent
1.6 Best efficiency point of pump Total flow of normally working pump shall
be the total condensate requirement at 100%
TG MCR and 1% MU.
1.7 Total dynamic head (TDH) at design capacity While establishing the design TDH the
following shall be considered and rounded
off to next higher 5 mlc:
(a) One twenty five percent (125%) of
deaerating feedwater heater operating
pressure at TG VWO
(b) A ten percent (10%) margin on
equipment and piping pressure drops at
TG VWO or 100% HP-IP-LP bypass
operation.
(c) Shall be selected such that pump would
be capable of meeting the TG VWO
requirement during an under frequency
operation of 47.5Hz.
1.8 Shut-off pressure Between 120% and 125% of pump design
total dynamic head and Curve shall be
continuously rising from runout to shutoff.
1.9 NPSH available (min.) Shall be based on condenser hotwell low
level
1.10 NPSH required at zero percent headbreak Shall not be greater than 80% of NPSH
available over the entire range of operation
from minimum flow to pump runout
1.11 Acceptable noise level at all operating
conditions
Not greater than 85 dBA at a distance of 1.0
m from the outline of equipment
1.12 Maximum speed rpm 1500
1.13 Maximum allowable vibration level at all mm/sec 8 (peak)
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380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
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operating conditions
1.14 Suction specific speed US units Not greater than 11,000
1.15 Condensate pH 8.6 to 9.2 during normal operation and 11 to
12 during alkaline flushing
1.16 Internal element Removable
1.17 Type of lubrication Self
1.18 Type of coupling Flexible type
1.19 Suction nozzle location Below mounting flange (top of suction piping
elevation shall be same as ground level)
1.20 Type of seals Mechanical seals
1.21 Thrust bearing type Kingsbury or equivalent
1.22 Thrust bearing location Between pump and motor
1.23 Reverse rotation protection Capable of withstanding reverse rotation due
to discharge NRV failure while system is at
maximum discharge pressure
1.24 Load sharing between pumps Not exceeding 5% over entire operating range
when operating with one or both pumps
1.25 Materials of Construction
1.25.1 Mounting flange Steel
1.25.2 Discharge elbow, Column pipe Carbon Steel
1.25.3 Suction bell, Bowl or casing, Discharge casing Cast Iron
1.25.4 Diffuser & guide vanes, cannister Carbon steel
1.25.5 Impeller Stainless steel
1.25.6 Shaft sleeves 11 - 13% chrome steel
1.25.7 Pump shaft 11 - 13% Forged chrome steel
1.25.8 Suction strainer Stainless steel
1.26 Codes And Standards
1.26.1 American Society for Testing & Materials
1.26.2 Hydraulic Institute Standards
1.26.3 ASME Performance Test Code for Centrifugal
Pumps
2.0 HRSG FEED PUMPS & ACCESSORIES
2.1 Number of HRSG feed water pumps for each
feed water pumping system
(a) Single-shaft configuration (i.e.,
independent ST for each gas turbine)
Two, (One working and one standby)
To be deleted as it is not applicable
(b) Multi-shaft configuration 2 X 100%, (One working and one standby)
2.2 Number of feed water pumping systems
(a) Triple pressure Combined HP feed water pump system with
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380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
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inter-stage tap-off for IP feed water system
And
LP feedwater pumping system
(b) Dual pressure HP feedwater pumping system
And
LP feedwater pumping system
2.3 Type of pump set
(b) LP Pumps Direct electric drive
2.4 Mode Continuous, either in single or in parallel,
from minimum flow to runout flow
2.5 Liquid handled Feed water and undeaerated feed water during
start-up.
2.6 Minimum temperature Ambient
2.7 Rated capacity of each pump Total combined flow of normally working
pump(s) shall be 110% of the total feedwater
flow at TG VWO, 1% MU and design cooling
water inlet temperature or 100% HP-IP-LP
bypass operation, 1% MU and design
condenser cooling water inlet temperature
together with any other feedwater
requirements, or any other condition causing
maximum feed water flow to be a maximum,
rounded off to nearest higher 10 cubic metre
per hour.
2.8 Best efficiency point of each pump Shall be of at feed water flow equivalent to
100% TG MCR and 1% MU
2.9 Total dynamic head at rated capacity Shall include 10% margin on equipment and
piping pressure drops for VWO condition or
100% HP-IP-LP bypass operation and shall be
rounded to next higher 5 mlc.
Shall be selected such that :
- Normally working pump would be
capable of meeting the TG VWO
requirement during an under frequency
operation of 47.5 Hz.
- Normally working pump would be
capable of meeting the requirements of
HRSG's MCR flow when drum highest
set pressure safety valve is relieving
2.10 NPSH available at (booster) pump centre line
for HP / IP pump and pump centre line for LP
pump (min)
2.10.1 Normal operation Shall not be less than three hundred percent
NPSH required at 3% head break by booster
pump for HP / IP pumps and LP pumps
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380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
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2.10.2 Transient operation Shall not be less than one hundred and twenty
five percent the NPSH required at 3% head
break by booster pump for HP / IP pumps and
LP pumps
2.11 Design speed for pumps
2.11.1 for booster pump of HP/IP pumps and LP
pump
rpm 1500
2.11.2 For barrel type main pump of HP/IP pumps
with variable speed hydraulic coupling.
rpm Around 5000 (Max 3000 rpm only)
2.11.3 for barrel type HP pump of constant speed
type.
rpm < 3000
2.12 Maximum suction specific speed US units Preferably not greater than 9500.
2.13 Shut-off head Shall be continuously rising from runout to
shut off and shut-off head shall be not less
than 120 and not greater than 125 percent
2.14 Load sharing between pumps Not exceeding 5% over entire operating range
when operating in parallel with other pumps
2.15 Minimum capacity of low flow recirculation Not less than 25% of pump rated capacity
2.16 Type of recirculation control Separate modulating type / automatic
modulating type recirculation valve (ARC)
2.17 Maximum noise level at all operating
conditions for the pump set comprising main
pumps, hydraulic coupling, booster pump,
drive motor
Not to exceed 85 dBA at a distance of 1.0 m
from outline of equipment. If maximum noise
level exceeds same, an accoustic enclosure
shall be provided. Accoustic enclosure if
provided, shall be of pre-fabricated modular
type with ease for assembly / disassembly
2.18 Maximum vibration level at all operating
conditions
VDI 2056 group G degree Good
2.19 Type of impeller Enclosed
2.20 Seals Mechanical seal confirming to API 682
2.21 Shaft Coupling Flexible type
2.22 Type of thrust bearing Kingsbury type or equivalent type
2.23 Strainer a) Fine mesh type with mesh size such that
same is less than minimum internal
clearance of the pumps during
commissioning.
b) Normal operation coarse strainer mesh
size as recommended by manufacturer
2.24 Materials of Construction
2.24.1 Outer casing applicable for barrel type pump Forged Carbon steel
2.24.2 Inner casing applicable for barrel type pump
and all stage casings for ring section type
pump.
ASTM A743 CA 6 NM
2.24.3 Impellers ASTM A743 CA 6 NM
2.24.4 Wearing rings 13 - 17% Chrome steel (Material shall be non-
galling type with differential hardness not less
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
Page 17 of 19
than 100 BHN)
2.24.5 Stuffing box bushing & stuffing box 13% chrome steel
2.24.6 Pump shaft 13% forged chrome steel
2.24.7 Shaft sleeves Stellite on 13% chrome steel
2.24.8 Base plate Structural steel
2.24.9 Diffuser / Volute 13% chrome steel
2.24.10 Strainer Stainless steel mesh
2.25 Hydraulic Coupling
2.25.1 Coupling wheels Alloy steel
2.25.2 Coupling wheels casing Alloy steel
2.25.3 Scoop tube Stainless steel
2.26 Thermal insulation Lightly bonded mineral wool with cladding.
Design thickness shall be based on outer
surface temperature of 600C under still air
condition with station ambient temperature of
300C
2.27 Codes And Standards
2.27.1 API 610 Eight Edition
2.27.2 American Society for Testing and Materials
(ASTM)
2.27.3 American Society of Mechanical Engineers
(ASME)
2.27.4 Hydraulic Institute Standards
2.27.5 ASME Power Test Code for Centrifugal
Pumps (PTC 8.2)
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
Page 18 of 19
1.0 DEAERATING FEED WATER HEATER
& ACCESSORIES
1.1 Type of deaerating feed water heater Spray - tray type / Spray type of Stork design or equivalent
1.2 Type of spraying arrangement Spray valves (variable flow area) / sprayer
assembly of Stork design or equivalent
1.3 Operation To match combined cycle power plant
requirements using steam supply from low
pressure line / auxiliary steam line
1.4 Design pressure of deaerator and feed water
storage tank
One hundred and twenty five (125) percent of
maximum extraction steam pressure or 4.5
kg/cm2(a) whichever is higher, rounded off to
next higher 0.5 kg/cm2 and full vacuum
1.5 Minimum design temperature of deaerator Compatible with heating sources temperature
or 2300C whichever is higher, rounded off to
next higher 50C
1.6 Minimum design temperature of feed water
storage tank
50 C higher than saturation temperature
corresponding to the design pressure or 2050C
whichever is higher, rounded off to next
higher 50C
1.7 Nett feed water storage tank capacity at 2/3rd
level (Normal) between normal level and top of
boiler feed pump suction in deaerator exclusive
of volume of any internal piping, baffles &
excluding volume of dished ends
6 minutes of feed water outflow at TG VWO,
1% MU condition with design CWIT
1.8 Other Requirements - In case desuperheater is provided on steam
line to deaerating feed water heater, the
deaerating feed water heater material shall
be selected taking into consideration the
condition of spray water failure.
- Safety valve on deaerating feed water
heater shall be sized to relieve the entire
steam quantity due to failure of control
valves on heating steam line to deaerating
feed water heater or alternatively an
additional safety relief valve shall be
provided downstream of the control valve
on the pipeline connecting deaerating feed
water heater.
1.9 Corrosion allowance over & above design code
requirements
mm 3.2
1.10 Pressure drop across spray valve assembly at
maximum condensate flow
kg/sq.cm 0.5 (max.)
1.11 Performance Guarantees Over Complete
Load Range
1.11.1 Maximum oxygen content in deaerated feed
water from 30% TG MCR to TGVWO with
1% makeup
cc/litre 0.005
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PIONEER GAS POWER LIMITED
380-425 MW COMBINED CYCLE POWER PLANT APSIPL-05EPC- 3-A6
STEAM AND WATER CYCLE EQUIPMENT
Page 19 of 19
1.11.2 Maximum carbon dioxide content in deaerated
feed water from 30% TG MCR to TGVWO
with 1% makeup
Nil
1.12 Materials Of Construction
1.12.1 Deaerating shell & heads Carbon steel to SA 516 Gr. 70 or equivalent
1.12.2 Feed water storage tank shell & heads Carbon steel to SA 516 Gr. 70 or equivalent
1.12.3 Trays Stainless steel to SS 304 / SS 431
1.12.4 Tray enclosure Stainless steel to SS 304
1.12.5 Spray valves / sprayer assembly Stainless steel to SS 304
1.12.6 Steam distribution pipe (Internal) / nozzles /
condensate pipes
Carbon steel to SA 106 Gr. B or equivalent
1.12.7 Splash plates & baffle plates Stainless steel to SS 304
1.12.8 Bolts SA - 193 B7 or equivalent
1.12.9 Nuts SA - 194 2H or equivalent
1.12.10 Gaskets CAF 40
1.12.11 Internal bolting, if any Stainless steel to SS 304
1.12.12 Vent orifice Stainless steel to SS 304
1.13 Thermal insulation Lightly bonded mineral wool with cladding.
Design thickness shall be based on outer
surface temperature of 600C under still air
condition with station ambient temperature of
300C
1.14 Codes & Standards
1.14.1 Heat Exchange Institute (HEI) Standards and
Typical specifications for Deaerators
1.14.2 American Society of Testing Materials
(ASTM)
1.14.3 ASME Performance Test Code for Deaerator
1.14.4 American Society of Mechanical Engineers
1.14.5 Indian Boiler Regulations