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GED Rubber Wood Fired Power Plant
Process Description
Pyry Energy Ltd. Vanit II Bldg, 22nd Floor, Room#2202
1126/2 New Petchburi Road Makkasan, Rajchthewi TH-10400
BANGKOK
Thailand
B 17 Oct 2014 Issued as per comment CRS MU MN
A 15 Sep 2014 Issued for Preliminary CRS MU MN
Rev Date Description Prepared Checked Approved Authorized
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REVISION HISTORY
Rev No. Date Detailed revision description
A 15 Sep 2014 Issued for Preliminary
B 17 Oct 2014 Issued as per comment
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TABLE OF CONTENTS
Clause Page
1 PURPOSE OF THIS DOCUMENT 6
2 GENERAL DESIGN DESCRIPTION 6
2.1 Reference Design Conditions 7
2.2 Design Life 9
2.3 Plant Operation 9
3. PROCESS DESCRIPTION OF INDIVIDUAL SYSTEMS 10
3.1 Fuel Receiving, Processing, Storage and Fuel Feeding System
10
3.1.1 Fuel Receiving Facility 10
3.1.2 Fuel Unloading and Storage 10
3.1.3 Fuel Processing Facility 10
3.1.4 Processed Fuel Storage 11
3.1.5 Fuel Feeding System 11
3.2 Steam Systems Description 11
3.2.1 Boiler 12
3.2.2 Main Steam System 12
3.2.3 Steam Turbine 12
3.2.4 Steam Admission 13
3.2.5 Steam Turbine Sealing Steam System 13
3.2.6 Steam Turbine Ejector System 13
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3.2.7 Steam Turbine Condenser 13
3.3 Water Steam Cycle/Balance Of Plant 14
3.3.1 Steam Bypass System 14
3.3.2 Startup Vent Valves 14
3.4 Water Treatment And Water Supply System 14
3.4.1 Raw Water Supply 15
3.4.2 Service Water System 15
3.4.3 Potable Water System 16
3.4.4 Condensate System 16
3.4.5 Feedwater System 16
3.4.6 Feedwater Deaeration 16
3.4.7 Feedwater Pumps 17
3.4.8 Blowdown 17
3.5 Flue Gas Cleaning System - Electrostatic Precipitator (ESP)
17
3.6 Ash And Dust Handling System 18
3.7 Chemical Storage and Dosing Systems 18
3.7.1 Boiler Chemical Dosing 18
3.8 Cooling Tower Chemical Dosing 19
3.9 Compressed Air System 19
3.10 Cooling Water Systems 19
3.10.1 Main Cooling Water Systems 19
3.10.2 Auxiliary Cooling Water Systems / Closed cooling water
Systems 20
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3.11 Waste Water Treatment / Neutralization System 20
3.12 Fire Protection and Detection System 21
3.13 Steam and Water Sampling System 22
3.14 Plant Control System 22
3.14.1 General Description 22
3.14.2 Plant Control Concept 23
ATTACHMENTS:
None
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1 PURPOSE OF THIS DOCUMENT
The purpose of this document is to provide an overview of the
conceptual design of power plant and description of process
including functionality of major subsystems and the major
components utilized within the power plant.
This document does not intend to give a detailed technical
description of all components within the power plant with their
design features and design considerations. For this level of detail
we refer to the individual design documents and calculations which
will be issued throughout the design phase of the power plants.
This document to reference with process flow diagram document
No. 9HX237380-000-001
2 GENERAL DESIGN DESCRIPTION
Gulf Energy Development (GED) is planned to construct a 20 MW
(net) power plant in Songkla province of Thailand. The Power Plant
shall produce net 20 MW electricity which will be supplied under
the SPP guidelines to the PEA Grid. The Plant design is based on a
configuration of one boiler, one steam turbine generator and
associated balance of plant. The following systems, major equipment
and facilities are envisaged:
Boiler.
Main Steam System including turbine bypass.
Steam Turbine Generator.
Condensate System.
Feed Water System.
Boiler Air and Flue Gas System.
Electrostatic Precipitators.
Ash and Dust Handling System.
Cooling Water Systems including Cooling Tower.
Chemical Storage and Dosing System.
Plant and Instrument Air Systems.
Fuel receiving, processing, storage and fuel feeding system
including mobile equipment for fuel handling.
Raw Water System including River Intake System and Raw Water
Pipeline.
Water Treatment Plant including Demineralization Plant.
Service Water System.
Potable Water System.
Fire Protection and Detection System.
Wastewater drainage, treatment and recovery systems.
Storm water Drainage.
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Roads and pavements.
Buildings including Plant Control Room, Workshop and warehouse,
office, etc.
115 kV Switchyard.
Electrical System including Medium Voltage and Low Voltage
Systems, electrical protection, DC/UPS System, earthing, area
lighting, etc.
Electrical room housing MV and LV switchboards, MCC, control and
protection equipment, UPS, etc..
DCS based Integrated Control and Monitoring system (ICMS).
Steam and Water Sampling System.
2.1 Reference Design Conditions
The design shall be based on the following design
conditions:
(1) Ambient Condition for Performance Guarantee
a) Ambient Pressure 1,009 mbar
b) Design Dry Bulb Temperature 32.8 deg C
c) Design Relative Humidity
78 %
(2) Ambient Temperature
a) Maximum Ambient Dry Bulb Temperature 38.2 deg C
b) Minimum Ambient Dry Bulb Temperature 19.7 deg C
c) Design Temperature for Electrical 32.8 deg C
(3) Relative Humidity
a) Maximum Relative Humidity 90 %
b) Minimum Relative Humidity 65 %
c) Design Relative Humidity 77 %
(4) Rainfall
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a) Annual Rainfall 1685 mm
b) 1 Hour Rainfall 85 mm
c) 15 Minute Rainfall 145 mm
(5) Wind speed (3 SecondGUST) 38 m/s
(6) Air Quality Slightly saline
(7) Site Level TBA
(8) Seismic Condition DPT.1302-52 and
ASCE7-05
(9) Noise Level < 85dB(A) at 1m from the
equipment
(10) Power Source
a) Frequency 50 Hz
b) Range of Frequency -1 % to +1 %
c) Motor power (=> 200kW) 6.6 kV, 3-phase
d) Motor power (< 200kW) 400/230 V, 3-phase
e) Lighting 230 V, 1-phase
f) Instrumentation 230 V, 1-phase
g) Control, Protection & Indication 220 V DC
(11) Motor
a) Protection Degree, Motor and Junction Box IP 54 for
Indoor
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IP 55 for outdoor
b) Winding Insulation Class F
c) Temperature Rise Class B
The Plant shall be designed for the full range of the ambient
air conditions presented in this table.
2.2 Design Life
The Works shall be designed for a minimum operational life of 25
years.
2.3 Plant Operation
Overall, the operational strategy is to design and construct the
Works for continuous operation. During the normal operation, the
plant is running mainly at base load in peak period and at about
65% in off peak period (night time). The works shall be designed
for operation in excess of 8000 hours per year (availability
guarantee is given separately). Even the works is expected to
operate mainly on maximum load; it shall be possible to operate the
works continuously in all load points of the capacity between the
minimum and maximum loads. During the design lifetime (200,000
hours), the works shall be designed to safe and efficient start-up
from hot, warm and cold conditions without exceeding permissible
levels of stress within components. It is of utmost importance that
the technical solutions used in the process shall secure energy
production in an environmentally safe way and with highest possible
thermal efficiency. The works shall be suitable for remote
automatic /manual operation from a control room by means of a
proven microprocessor based, functionally grouped and
hierarchically structured control and information system (DCS).
Full sequence control shall be provided to facilitate automatic
start up and shut down of the units and their auxiliary systems
with minimum plant attendance.
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3. PROCESS DESCRIPTION OF INDIVIDUAL SYSTEMS
3.1 Fuel Receiving, Processing, Storage and Fuel Feeding
System
Rubber wood stumps will be transported from the areas of
plantation by trucks (provided by
others) to the site.
3.1.1 Fuel Receiving Facility
The receiving facility will be purpose-built to suit the
following criteria:
Each truck shall be weighed before and after the wood is
unloaded.
It is expected that approximately 50 trucks will deliver fuel
each day.
The facility will be open to accept deliveries seven days a week
between the hours of 7 am and 7 pm.
Each truck can carry up to 20 metric tons of wood.
The facility shall suit weighing and unloading from a trailer
truck.
3.1.2 Fuel Unloading and Storage
The fuel yard will be located within the Plants security fence
with dedicated access. The wood
from the trucks shall be unloaded from trucks and stored in the
open yard using mobile
equipment. The unloading and storage facility shall be
purpose-built to suit the following
criteria:
The fuel yard shall be sized to hold the fuel required for 14
days with the boiler operating at Maximum Continuous Rating.
The wood shall be stacked in a way that would allow natural
drying.
The ground storing the tree stumps will be asphaltic concrete 50
mm thk. pavement.
The stock-piling arrangement will facilitate easy loading of
stumps for cleaning.
The mobile equipment used for stacking and un-stacking will be
fit for the requirements stated above.
3.1.3 Fuel Processing Facility
This facility will receive wood from the open storage yard and
clean and process the wood to
produce chips meeting the fuel size specification. Stumps will
be picked using mobile
equipment and be cut in smaller size before chipping. Raw wood
will be fed by passing
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through disc screen to remove sand /stone before chipper. Then
wood chipper will cut the raw
wood into specific chip size as processed wood chip and
forwarded to processed fuel storage
area. Fuel processing facility shall be concrete pavement with
roof shed at wood chipper to
protect from rain.
3.1.4 Processed Fuel Storage
The processed fuel storage building shall be sized to hold a 3
days fuel supply to the boiler.
The wood chip will be stored in enclosed building to prevent
contamination of fuel with soil,
rock or stones and rain. The building includes with natural roof
ventilation for wood
dehumidification and prevents dust hazards. This area will be
sized to contain fuel
requirements of the boil at MCR condition. This area may be
divided into two sections to allow
storage and reclaiming simultaneously.
3.1.5 Fuel Feeding System
The wood chips will be reclaimed from the storage area and
transferred to a reclaiming hopper
pit. The fuel hopper will be suitable for receiving wood chips
from self-unloading trailers, dump
trucks, front-end loaders or conveyors. The fuel feeding system
will be equipped with tramp
metal separators.
The wood chips from the reclaiming hopper will be conveyed to a
surge silo from which wood
chips will be conveyed to a day bin which can store 6-hour fuel
requirements of the boiler at
MCR conditions. The wood chips from the day bin will be metered
and fed to the boiler by
screw feeders.
3.2 Steam Systems Description
The entire system process flow is a complete system of water and
steam recirculation
process.
The super-heated steam from boiler after heat exchanging enters
into steam turbine to drive
turbine and generator to generate power. The steam after driving
turbine will be cooled down
into water in the condenser. The feed water will enter into
boilers economizers for heating up
through feed water pump. The high temperature water after
heating up economizer. Feed
water then mixes with the saturated liquid in the steam drum and
the steam/water mixture
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rising from the generating circuits and enters into the steam
turbines. Consumed water can be
made up by the demineralized water from demineralizer at
circulation process.
3.2.1 Boiler
Boilers are pressure vessels designed to produce high pressure
steam in which water under pressure is transformed into steam by
the application of heat. In the boiler furnace, the chemical energy
in the fuel is converted into heat, and it is the function of the
boiler to transfer
this heat to the contained water in the most efficient
manner.
A boiler to absorb the maximum amount of heat released in the
process of combustion. This
heat is transferred to the boiler water through radiation,
conduction and convection.
The rubber wood fuel is transferred into the combustion system
by biomass feeding. From the combustion system the hot gasses pass
through the boiler and super heater for heat energy transfer.
Steam is fed form the collecting steam drum to the steam turbine
generator. The turbine turns a generator through a reduction gear
set. Exhaust steam is condensed and routed through the
boiler feed water systems and then pumped to the economizer.
Refer to Technical Specification for Rubber Wood Fired
Boiler.
3.2.2 Main Steam System
From the boilers, the main steam with the main steam supply will
go through the main steam
pipe and the main steam stop valve, and the governor main valve
before entering the steam
turbine.
In order to achieve convenient normal operation and emergency
start and stop there is a main
steam bypass system and piping. When the pressure exceeds the
settling value of the main
steam governor valve, it will automatically open partly and the
excessive steam can directly
enter into the main condenser, to keep the pressure of turbine
inlet constantly. After the De-
superheater the steam pipe is connected to the condenser.
3.2.3 Steam Turbine
Refer to Technical Specification for Rubber Wood Fired Steam
Turbine.
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3.2.4 Steam Admission
The HP steam enters the HP turbine by one HP Steam inlet line.
At the inlet of the steam turbine a main stream stop valve is
installed to interrupt the steam supply in case of a steam turbine
trip.
3.2.5 Steam Turbine Sealing Steam System
For sealing purposes of the steam turbine, HP steam from the
common HP steam line is supplied to the steam turbine glands during
start-up/shut-down. During low load operation the sealing steam is
supplied by the steam turbine bleed (extraction) steam system. The
sealing steam is controlled at a slight over-pressure by a pressure
reducing control valve. The vacuum side of the steam turbine glands
is kept at a pressure below atmospheric by one (1) 100% ejector
steam condenser. The gland steam is condensed in the ejector steam
condenser by the main condensate water and the drain is fed to
condenser hot well.
3.2.6 Steam Turbine Ejector System
The vacuum in the condenser is being established and maintained
by the ejector steam system. The initial vacuum is being
established by the startup ejector. After initial vacuum the normal
ejector will take over and will establish the operational vacuum
pressure.
3.2.7 Steam Turbine Condenser
The condenser is horizontally arranged water cooled surface type
to transfer heat from ST
Exhaust steam to the cooling water to condensate the steam
coming out of the steam turbine.
Also steam turbine bypass valves lines are connected to exhaust
transmission duct between
ST exhaust and condenser to condense the steam in the condenser
during start up, shutdown
and emergency case. A condenser LP flash box to collect ST
starting drains is installed. A
condensate water recirculation pipe to keep minimum flow rate
through the condensate
extraction pumps is connected to the condenser.
A demin water make-up line is connected to the condenser hot
well to make up for the losses
of the water/steam cycle. These losses consist of start-up
losses, Boiler blowdown losses or
export steam condensate return losses in case the export steam
condensate is off
specification.
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3.3 Water Steam Cycle/Balance Of Plant
3.3.1 Steam Bypass System
A steam turbine bypass system is incorporated in the design to
maximize operation and start
up flexibility of the plant. The proposed capacity of the
turbine bypass valve is 60% of the main
steam flow at the boilers maximum continuous rating. The bypass
system will be operated in
the following cases:
- Start-up and shutdown after vacuum has been established in the
steam turbine
condenser.
- To prevent boiler tripping, when the steam turbine trips.
- High pressure at the inlet of the steam turbine in the steam
lines.
Each individual bypass system consists of a steam stop valve, a
pressure reducing station and
spray water control valve and spray station (integrated in the
pressure control valve).
Downstream of the spray station a temperature transmitter is
installed to alarm in case of
malfunction of the spray station. The water for the spray
station is taken from the main
condensate line, immediately downstream of the condensate
pumps.
3.3.2 Startup Vent Valves
When the power plant is started from cold conditions no vacuum
can be established in the
system turbine condenser. In order to assure steam flow through
the Boiler systems and
prevent overheating of the boiler tubes, a HP start up vent
valve is installed in the HP steam
lines. The start-up vent valves will be used during initial warm
up and these valves will control
the pressurization of the Boiler HP systems until the steam
turbine condenser has established
vacuum and the bypass stations have been released for control.
When the bypass stations
have been released for control, the start-up vent vales will be
closed and the bypass station
takes over the pressurization of the boiler systems.
3.4 Water Treatment And Water Supply System
The overall objective of boiler feed water treatment is
generally to reduce the hardness, the silica or the total dissolved
salts concentration in the feed water. Because the processes that
achieve this, (for example ion exchange) can themselves be fouled
by some raw water
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contaminants, it is normally also necessary to pre-treat the raw
water before it enters the boiler feed water treatment system.
Typically, the treatment processes are required to remove the
following types of contaminants: The water treatment plant consists
of pre-treatment and a demineralization plant to treat raw
water to the quality required by the boiler.
Raw water first flows into conventional clarifiers. The
clarified water will be stored in a clarified
water tank and will be used as process water and feed to the
demineralization plant. For the
production of demineralization water, the clarified water will
be pumped to a sand filter for
removal of residual suspended solids and to the granular
activated carbon filter for removal of
organic constituents.
Dissolved solids are removed by the demineralization plant.
Demineralization plant consists of
cationic and anionic exchangers. Demineralized water is further
polished by mixed bed
exchangers before been stored in the demineralized water storage
tank. The consumers of the
demin water are:
-The condenser for cycle make-up.
-Deaerator.
-Boiler chemical dosing skid.
-Closed cooling water head tank for CCW system.
-Laboratory and regen water by demineralized water pumps.
The regular consumer is the condenser make up system where the
steam cycle losses adding
demin water to the condenser. Other consumers are minor.
3.4.1 Raw Water Supply
Raw water is drawn from the river situated from the plant.
2x100% raw water intake pumps are provided to extract the water
from the river to a raw water
pond via a pipeline. The raw water is pumped into clarifier from
the raw water pond. Raw water
is used for firefighting. Fire water pumps discharge raw water
to the firewater ring main.
3.4.2 Service Water System
A service water distribution system is provided in the Plant.
Water from the raw water pre-
treatment plant is used for service water. The output of the
pre-treatment plant is stored in the
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service water tank 2 x 100% Service water pumps supply service
water for washing and
cleaning purposes in the plant. 2 x 100% Make-up water pumps
supply make-up water to the
cooling tower.
3.4.3 Potable Water System
A potable water system is provided to supply water for drinking
and eye wash showers. The
principal methods of disinfection are irradiation by
ultra-violet light. Ultraviolet (UV) light kills
micro-organisms by short-wave light that destroys their
molecular structure.
3.4.4 Condensate System
The turbine exhaust steam flows to a shell and tube condenser
vessel where heat is rejected
via cooling water flowing through the tubes. Condensing steam
collects in the bottom of the
condenser vessel the hotwell. The Condenser hotwell forms a
reservoir for the condensate
extraction pumps. Various flows from the steam and water circuit
(e.g. gland steam, turbine
drains, CEP min flow, etc) are returned to the condenser to
conserve heat and prevent water
leakage from the system. No condenser tube cleaning system is
proposed as the cooling
water is clarified river water and is chemically dosed to
prevent biological growth and scaling.
Condensate is pumped from the Condenser to the Deaerator by 2 x
100% Condensate
Extraction Pumps, via a Gland Steam Condenser and Low Pressure
Heater. The LP Heater is
a shell and tube heat exchanger which obtains steam from the
steam turbine. The condensate
from the LP Heater is drained to the Condenser. The gland steam
condenser is a shell and
tube heat exchanger which collects and condenses the gland steam
from the turbine seals.
A vacuum skid extracts air from the condenser during start-up,
and helps to maintain
condenser vacuum during operation. The vacuum in the condenser
is established and
maintained by the steam ejectors.
3.4.5 Feedwater System
Condensate from LP Heater flows to a Deaerator.
3.4.6 Feedwater Deaeration
The system consists of a feedwater deaerator and feedwater tank.
It has the following tasks:
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Buffer tank for compensating the relatively short-time mass flow
fluctuations between feed water demand and condensate return flow
(start-up of the plant or steam turbine trip, process condensate
losses),
Deaeration of the returned condensate and make-up feedwater,
i.e. expulsion of entrapped oxygen and other non-condensable
gases,
Feedwater heating.
The water level in the deaerator is automatically regulated by
the plant control system.
The design uses sprays of steam and bubbles of steam in the
water to extend the steam water
interface and achieve the necessary steam/water contact. Steam
is supplied from the turbine
bleed while condensate is supplied from the steam turbine
condenser via the LP feedwater
heaters.
3.4.7 Feedwater Pumps
The feedwater pump extracts the deaerated feedwater from the
feedwater storage tank and
feeds it to the economiser. A minimum flow device is provided to
ensure a minimum flow
through the pump under conditions of minimum or no-flow of
feedwater to the boiler.
The drum level of the boiler is kept at a constant value by the
feedwater control valve ahead of
the boiler inlet by three-element control.
The multi-stage boiler feed pumps (2 x 100%) complete with
leak-off valves, gauges, guards
and couplings will be supplied. Each pump will be provided with
a constant speed electric
drive. The pumps are of horizontal, multistage, segment casing
design held together by high
tensile tie-bolts.
3.4.8 Blowdown
Boiler water quality is maintained by operation of the
continuous and intermittent blowdown
valves. A Blowdown Vessel is provided to receive continuous
blowdown. Also, all boiler drains
are connected to blow down tank.
3.5 Flue Gas Cleaning System - Electrostatic Precipitator
(ESP)
Electrostatic Precipitators are proposed for fly ash extraction.
The gases enter the ESP
horizontally via the inlet, where the gas velocity is evened out
over the whole ESP section by
means of a gas distribution system. The ID fan is installed
after the ESP.
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On the application of high current, the dust particles are
separated on the collecting plate
when passing through the inter electrode spacings.
Both the electrode and the discharge electrode system are
cleaned by mechanical, electric-
motor driven rapping devices and thus kept clean. By means of
these periodically operating
rapping devices, which are freely programmable for each field
with regard to operating and
interval time, the dust is hence loosened due to the shearing
forces and falls into the hopper.
3.6 Ash And Dust Handling System
Handling of ash is basically divided into wet bottom ash, dry
fly ash. Bottom ash is the material
that is collected beneath the furnace or combustion chamber
while fly ash is typically fine dry
ash particles that are suspended in the flue gas and collected
at various points downstream of
combustion flue gas path.
The furnace ash handling is a wet system while ash and dust from
the economiser/airheater
and emission control is handled by a dry system. Furnace bottom
ash falls into the waste
water pit bottom onto a water submerged conveyor that
continuously discharges the ash form
the furnace.
A submerged conveyor in circulating water is used to:
- Keep conveyor surfaces cool
- Provide an air-tight seal in the furnace that protects the
furnace from air infiltration
- Extinguish any burning or glowing combustion residues
- Lower the temperature of wet ash for convenient disposal
external to the boiler
Whilst the dust from the air heater, economiser and ESPs is
chain or belt conveyed to an ash
storage silo for disposal by a truck.
3.7 Chemical Storage and Dosing Systems
3.7.1 Boiler Chemical Dosing
One high pressure chemical dosing unit is included, for the
intermittent injection of scale inhibitor chemical to the steam
drum, and two low pressure pumps for dosing oxygen
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scavenger and ammonia. The dosing system includes pumps, mixing
tank (or bulky bins), agitator, instruments and associated
valves.
3.8 Cooling Tower Chemical Dosing
The dosing system for the circulating water consists of
hypochlorate dosing for preventing
biological growth and Acid pH Control.
3.9 Compressed Air System
The compressed air system comprises of an instrument air system
and service air system.
2x100% capacity compressors (1 x duty, 1 x standby) supply air
to one air receivers operating in parallel, sized for a five
minutes uninterrupted supply of instrument air.
Compressed air from the air receivers passes through two sets of
coarse filters meeting the required service air quality. A common
air header from the air receivers supplies air to both the
instrument air header and the service air header.
Service air is taken directly from the common air header with an
actuated isolation valve to isolate the service air header from the
instrument air header in event of pressure drop or fluctuation.
Instrument air only is then passed through the refrigerant type
air dryer and two sets of secondary (fine) filters to remove any
condensed liquids, particulates and oil vapours to ensure air
provided is of instrument air quality.
3.10 Cooling Water Systems
3.10.1 Main Cooling Water Systems
The cooling water system is delivering the cooling water to
turbine condenser to cool down the
exhaust steam into condensate water, the system is a closed
circuit system, the cold water
from goes to the condenser, after cooling process the water is
going back to the cooling tower
after temperature rise, where the temperature of the hot water
is cooled down to certain level
for continuing the process. Cooling tower water source is taking
from raw water pre-treatment
system.
An induced-draught mechanical wet cooling tower system transfers
the waste heat of the
water-steam cycle to the atmosphere. The cooling tower consists
of two (2) separate cells.
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Two (2) x 50% main cooling water pumps supply the cold water
from the cooling tower water
basin to main condenser.
The cooling water quality is controlled by water blowdown
through the cooling tower blow down valve. In the main cooling
water supply line a pH and a conductivity analyzer are installed
for on line monitoring of the cooling water quality. The
conductivity measurement is used for the control of the cooling
water blow down valve against the conductivity setpoint given by
the operator. The pH meter is used for the control loop for dosing
acid to control the pH value of the Main Cooling Water.
3.10.2 Auxiliary Cooling Water Systems / Closed cooling water
Systems
The main circulating water pumps direct the cooling water to the
condenser and the auxiliary
coolers. 2X100% Auxiliary Cooling Water Pumps operate in closed
cycle supplying clean,
treated cooling water to the following auxiliary equipment. The
auxiliary cooling water pumps
work in a so called duty/standby arrangement. The stand-by pump
will start in case of
electrical failures or cooling water pump outlet pressure
decreases to certain level.
As the name the closed cooling water system is a separated
closed loop system.
The closed cooling water (CCW) system is cooling the following
components:
The turbine lubes oil coolers.
The generator air coolers.
The sampling coolers.
Feed pump bearing coolers.
Boiler fan bearing coolers.
Vacuum pump coolers.
ID Fan.
Ash screw cooler.
3.11 Waste Water Treatment / Neutralization System
Waste water from the demineralization plant is combined with
drain from boiler blowdown tank
before being routed to a waste water pond.
Within the power plant a 313.2 m3/day waste water pond has been
constructed.
This pond collects all waste water streams. These streams
are:
- Waste water from Demin plant neutralization basin.
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- Waste water from oil water separator.
- Blow down from cooling tower.
- Treated building waste water.
- Treated oily water.
Two (2) x 100% transfer treated waste water pump have been
installed at the transfer treated waste water pit which is
connected to the waste water pond through an underground line. To
check the quality of the waste water before being discharged to
public. When the quality is within the limits the discharge
open/close valve opens and the recirculation open/close valve
closes and the waste water is being pumped out to public drainage.
HDPE sheet lining is provided to prevent environmental impact. The
waste water pond may need to provide sub-drainage system with sump
pump to prevent floating of HDPE sheet lining in case of high level
of ground water which depends on site condition.
3.12 Fire Protection and Detection System
The power plant is equipped with a fire fighting system. For
safety and reliable this system
necessary to have the fire water pumps which the purpose. The
following pumps have been
installed within the power plant:
- 1 x 100% jockey pump to maintain the pressure in the
system.
- 1 x 100% electric motor driven fire water pump.
- 1 x 100% diesel engine driven fire water pump.
The pumps draw their water directly from the raw water pond
which sufficient to serve the
highest fire scenario according NFPA 850(highest water demand
volume plus 1 set hydrant
operating)
The firefighting water is distributed over the power plant
through a ring main pipe distribution
network to the outdoor hydrant stations, the deluge water spray
system shall be provide for
main transformers switch yard area , Auxiliary Transformer
,Steam Bearing and fuel oil tank
respectively. The fire hose cabinet shall be provided for indoor
building. The firefighting system
is monitored by link the signal from each local panel of fire
pump via to the Main Fire Alarm
Control Panel (FACP) which is installed in the control room. The
FACP also monitors the
smoke and heat detectors installed at different locations and
alarms when a detector is
activated.
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3.13 Steam and Water Sampling System
To ensure the safe and economic operation of biomass boilers and
steam turbine generators and to monitor and control the waste gas,
waste water. A testing laboratory shall be set up in the plant for
chemical analysis and a steam-water online analysis sampling device
shall also be set up. All online analysis devices can convert
measured data into 4-20mA standard signals which shall be sent to
the computers in central control room, to facilitate operators'
routing inspection and recording & printing.
The chemical condition of the steam and feedwater system is
monitored on-line by means of
the following samples:
Condensate Pump Discharge Conductivity, Cation, Conductivity,
pH.
Condensate to Deaerator Conductivity, Cation Conductivity,
pH.
Deaerator Outlet Conductivity, Cation Conductivity, pH,
Dissolved Oxygen.
Drum Water Conductivity, pH, Sodium, Dissolved Oxygen.
Saturated / Superheated Steam Conductivity, Cation
Conductivity.
The steam water analysis system is composed of followings:
High temperature and high pressure rack: Functioned for high
pressure steam water temperature/pressure reducing. Includes at
least pressure reducing valves, cooler and valves accessories. Low
temperature instrument sampling device: Composed of low temperature
instrument panel and manual sample rack. Includes at least all
components required for sample testing, sampling, alarming, signal
transfer, automatic protections, pipelines, electric devices,
control instruments and valves. Demin. water cooling device
includes heat exchangers, water storage tank and circulation
pumps along with relevant pipelines, pipe fittings, valves. The
devices are mounted on a
frame.
3.14 Plant Control System
3.14.1 General Description
The plant control system operates under all conditions such as
normal power operation, cold and warm start-up, load rejection,
island operation, and shutdown in automatic mode or
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manually controlled by the operators at operator workstations in
the Central Control Room (CCR).
All open loop and closed loop control systems or process control
stations are based on distributed digital control with built-in
redundancy and interconnected via a redundant high speed bus
system(s).
A redundancy provides for the process and/or instrumentation is
considered in DCS to further improve overall system
availability.
The single failure criteria are applied. This means that a
single failure in any part of the DCS is not lead to a trip of a
plant main component, e.g. GT or ST or Generator, etc. or the plant
itself.
Closed loop and open loop controls, as well as protective
interlocks of all Power Plant equipment is implemented in the
Distributed Control System (DCS) and in the specific packaged plant
control system.
Exhaust stack emissions are monitored through EPA/CARB certified
continuous emissions monitoring system (CEMS). Emissions monitored
include: Sulfur dioxide (SO2), Oxides of Nitrogen (NOx), Oxygen
(O2), Carbon Monoxide (CO), Carbon dioxide (CO2), opacity and
Particulates.
3.14.2 Plant Control Concept
The plant control concept is based on the following:
- Overall Distributed Control System DCS for the whole power
producing process including its sub-systems.
- Microprocessor based DCS.
- Maximum safety for personnel and equipment.
- Safe, reliable, and efficient operation under all
conditions.
- Very high availability.
- Highest degree of automation, including total plant start-up,
shutdown.
- Providing all data required for operation, maintenance, and
performance optimization.
- Hierarchical structure of the controls.
- Start-up and shut-down of the plant in automatic sequence
(unit controller). The unit controller allows an automatic
start-up/shut-down of the plant by means of sequencers. The
sequencer monitor all of "permissive to start parameters" to allow
the plant start-up. These "ready for start-up conditions" include
appropriate feedbacks yielded with some manual operations executed
locally and with equipment in service to permit its automatic
start-up. Some mode selections made on VDU screens prior to plant
start-up (i.e. automatic or parallel with electric grid, cold or
warm start-up, etc.) to activate the type of start-up sequence
(manual, semi-auto with operator consents to proceed or
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fully automatically).
- Functional groups i.e. sequence control for Steam turbine,
Boiler, Water/Steam-Cycle, Balance of Plant and Electrical
Equipment, etc.
- Functional sub-groups for sub-systems (i.e. redundant
systems).
- Functional drive control with standardized function
blocks.
- Plant coordination level (droop/isochronous mode, load
rejection recover, island mode, etc.).
- Process control level (level control, temperature control,
pressure control, etc.).
- Single control valve 1drive level (position control, speed
control, etc.).
- Quality of design extensively proven.