GAIL Summer Training 2013 1 S.No. Page No. 1 Acknowledgement 02 2 Introduction 03 3 History 05 4 Integrated Offsite Plant & storage 06 5 Downstream 24 6 Upstream 36 7 Conclusion 55
Jul 06, 2015
GAIL Summer Training 2013
1
S.No. Page
No.
1 Acknowledgement 02
2 Introduction 03
3 History 05
4 Integrated Offsite Plant & storage 06
5 Downstream 24
6 Upstream 36
7 Conclusion 55
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I would like to take this opportunity to thank everybody ,
who has helped me in course of undergoing training at
UPPC, GAIL , PATA from 10-jun-2013 to 08-jul-2013.
As a special mention I extend my sincere thanks to Mr.
John Kutty (HRD) & Shri. V.K.Purwar (SM, F&A) for their
kind support in helping me get settled in an entirely new
space to work and gain.
I also give my whole hearted thanks to Mr. Ajay Tripathi
(DGM-Mech.) ,Mr. G.C.Pandey(CM),Mr. Shrikant
Verma(Chief Er.),Mr. Neeraj(Er., GPU),Anil Nair(DM, Lib.)
for their guidance and supportive nature during the
training period and for the completion of report.
I am very thankful to Mr. H.N. Gupta(visiting faculty) for
enhancing my technical knowledge which made the
understanding of practical concepts easy.
At last I wish to extend my sincere thanks and gratitude
to all GAIL employees for their co-operation and ever
helping attitude thet helped me in my quest for complete
understanding of plant and various processes.
Navin Dixit
B.Tech(ME)
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GAIL (India) Limited, is India's flagship Natural Gas
company, integrating all aspects of the Natural Gas value
chain (including Exploration & Production, Processing,
Transmission, Distribution and Marketing) and its
related services. In a rapidly changing scenario, GAIL is
spearheading the move to a new era of clean fuel
industrialisation, creating a quadrilateral of green
energy corridors that connect major consumption centres
in India with major gas fields, LNG terminals and other
cross border gas sourcing points. GAIL is also expanding its
business to become a player in the International Market.
Today, GAIL's Business Portfolio includes -
* 7,700 km of Natural Gas high pressure trunk pipeline
with a capacity to carry 157 MMSCMD of natural gas
across the country
* 7 LPG Gas Processing Units to produce 1.2 MMTPA of LPG
and other liquid hydrocarbons
* North India's only gas based integrated Petrochemical
complex at Pata with a capacity of producing 4,10,000 TPA
of Polymers
* 1,922 km of LPG Transmission pipeline network with a
capacity to transport 3.8 MMTPA of LPG
* 27 oil and gas Exploration blocks and 3 Coal Bed
Methane Blocks
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* 13,000 km of OFC network offering highly dependable
bandwith for telecom service providers
* Joint venture companies in Delhi, Mumbai,
Hyderabad, Kanpur, Agra, Lucknow, Bhopal, Agartala
and Pune, for supplying Piped Natural Gas (PNG) to
households and commercial users, and Compressed
Natural Gas (CNG) to the transport sector
* Participating stake in the Dahej LNG Terminal and the
upcoming Kochi LNG Terminal in Kerala
* GAIL has been entrusted with the responsibility of
reviving the LNG terminal at Dabhol as well as sourcing
LNG
* GAIL Gas Limited, a wholly owned subsidiary of GAIL
(India) Limited, was incorporated on May 27, 2008 for the
smooth implementation of City Gas Distribution (CGD)
projects. GAIL Gas Limited is a limited company under the
Companies Act, 1956.
* Established presence in the CNG and City Gas sectors in
Egypt through equity participation in three Egyptian
companies: Fayum Gas Company SAE, Shell CNG SAE and
National Gas Company SAE.
* Stake in China Gas Holding to explore opportunities in
the CNG sector in mainland China
* A wholly-owned subsidiary company GAIL Global
(Singapore) Pte Ltd in Singapore
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GAIL (India) Ltd. (erstwhile Gas Authority of India Ltd),
India's principal gas transmission and marketing
company, was set up by the Government of India in August
1984 to create gas sector infrastructure for sustained
development of the natural gas sector in the country.
The 2800-km Hazira-Vijaipur-Jagdishpur (HVJ) pipeline
became operational in 1991. During 1991-93, three LPG
plants were constructed and some regional pipelines
acquired, enabling GAIL to begin its regional gas
distribution in various parts of India.
GAIL began its city gas distribution in Delhi in 1997 by
setting up nine CNG stations, catering to the city's vast
public transport fleet.In 1999, GAIL set up northern India's
only petrochemical plant at Pata.GAIL became the first
Infrastructure Provider Category II Licensee and signed
the country's first Service Level Agreement for leasing
bandwidth in the Delhi-Vijaipur sector in 2001, through
its telecom business GAILTEL. In 2001, GAIL commissioned
world's longest and India's first Cross Country LPG
Transmission Pipeline from Jamnagar to Loni.GAIL today
has reached new milestones with its strategic
diversification into Petrochemicals, Telecom and Liquid
Hydrocarbons besides gas infrastructure. The company has
also extended its presence in Power, Liquefied Natural Gas
re-gasification, City Gas Distribution and Exploration &
Production through equity and joint ventures
participations.
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&
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INTRODUCTION TO POWER PLANT
Power Plant in U. P. Petrochemical Complex comprises 3
Nos. Utility Boilers each having Steam Generating
Capacity of 120 TPH at MCR, at pressure 106 Kg/Cm2 (g)
510 o
C.
The Steam Generated from all these boilers is utilised
for production of Electrical Power in 2 Nos. of Turbo
Generators having Generating Capacity of 15.5
MW(Extraction type) & 25.6 MW(Condensing type) in
addition to meeting demand for process steam
requirement in different section of the complex . The high
pressure steam (106 Kg/Cm2
(g) ) produced from all the 3
boilers is connected to a common header from where
steam is fed separately to 2 nos. of steam turbines , serving
as prime mover to rotate 2 nos. of generators.
Normally, these boilers are meant for producing steam at
very high pressure (105 Kg/Cm2
) but depending on process
requirement this VHP steam is led down to high pressure
(40 Kg/Cm2
) , Low medium pressure (8.0 Kg/Cm2
) and Low
pressure at 4.0 Kg/Cm2
.
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UTILITY BOILER
A- Construction Details:
Make : M/s BHPV
Boiler Designation: 17.3 60
F VU 6 0 36
26 2
Where F- Stands for : Furnace
17.3 : Width of furnace in feet
26 :Length of furnace in feet
VU : Vertical Unit.
2 : Diameter of Bank tube in inch
36 : ID. of Lower drum in inch
Location : Semi out Door
Boiler Type : Natural Circulation, BI-Drum, Front
Wall Fired Forced Draft Furnace, Radiant Closed Bottom
Suitable for Oil/Gas Firing
Fuel : Rich Gas
: Lean Gas
: Combination of Blended
fuel oil & Rich Gas.
GENERAL DESCRIPTION OF BOILER
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The steam generator is a natural circulation water tube
design arranged for forced draft firing . Basically it is a
two drum vertically bent tube arrangement with water –
cooled furnace walls combined with convective boiler
bank surfface. The furnace is specifically designed to suit
for 10% excess air operation for gas firing . The complete
furnace section is of the welded wall type arranged as a
gas and pressure tight envelope which eliminates the
problem of casing corrosion and cumbersome refractory
maintenance , besides this provides structural rigidity for
the unit . The complete steam generator is of the bottom
supported design resting on concrete pedestals .
The conservatively sized upper and lower drums are
connected by the bank tubes . The steam drum is provided
with simple and efficient drum internals ,resulting in
high steam quality at all loads of boiler outputs .
Unheated downcomers are located in the boiler bank
sides.
The boiler bank tubes are arranged in line for best heat
absorption , minimum tube draft loss and for easy
inspection and cleaning . Required accessibility is
provided at the front & rear side of the boiler bank
convective surface . Adequate peepholes are also provided
to watch the flame.
The feed water from economiser is fed into the steam
drum. Circulation is maintained in the boiler bank
through the downcomers . From the bottom drum, water
flows through the heat absorbing furnace tubes and back
into steam drum .After separation of moisture in the steam
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drum the saturated steam flows into the superheater . The
superheater system has two sections. They are radiant
platen pendent section (arranged at the outlet of
furnace) and the final superheater adjacent to platen
section. A desuperheater is provided in-between the two
sections in the connective links for controlling the
superheater temperature over the wide load range . The
location and selection of superheater is so chosen that the
specified temperature of superheater achieved between 30
to 100% MCR load of the boiler .
The firing system consists of 4 No. of burners designed for
gas firing located in the font wall . Gas igniters are
provided for lighting the burner . The flame scanning
system is provided to monitor the main flame condition in
the furnace.
1 No. Forced draft fan with dual drive (motor + steam
turbine ) will supply the complete combustion air at the
required pressure for the boiler.
A bare tube in line economiser is provided as the last
heat recovery section.
The complete integral piping , valves and fitting, air
and gas ducting, all refractory and insulation materials
are provided.
Feed water is supplied to the steam drum from the feed
storage tank through feed line. The water side of the steam
drum is connected with lower drum through boiler bank
tubes . Furnace side walls inlet headers are supplied with
water from lower drum through supply tubes. The steam
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water mixture generated in the side walls are collected in
the side wall outlet headers and from where it is
discharged into the drum through a system of riser tubes.
Boiler water from the lower drum is fed into the front walls
through floor panels and discharged into steam drum as
steam water mixture . Likewise rear wall receives the boiler
water from lower drum and discharges to the steam drum.
B - ECONOMISER
The purpose of the economiser is to preheat the boiler feed
water before it is introduced into the steam drum, and to
recover some of the heat from the fuel gases leaving the
boiler.
The economiser is located in the second pass of the
boiler. Each section is composed of a number of parallel
tube circuits, arranged in horizontal rows. All tube
circuits originate from inlet header and discharge into
outlet header. Feed water is supplied to the economiser
inlet headerfrom FEED CONTROL STATION. The feed water
flow is upward or downward through the economiser that
is in counterflow to the hot fuel gases . Most efficient heat
transfer is thereby accomplished . Any chance of steam
generation within the economiser is eliminated . From the
outlet header the feed water is led to the drum.
Before starting up the boiler, the economiser should
be inspected externally and if necessary cleaned .
Especially if the installation is new, accumulation of
erection material is not unusual. Large debris should be
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removed manually , followed by the washing down the
economiser banks by means of hose and water.
All joints in the economiser casing should be
examined occasionally for tightness in order that air in
filtration be kept to minimum. Insulation should be kept
in good condition.
C - SUPERHEATER
It is non drainable superheater , pendant type . The
superheater coils are suspended below the superheater
header.
No. of coils in Primary Super Heater (PSH ) - 13
No. of coils in Final Super Heater (FSH ) – 47
D - DESUPERHEATER
Desuperheater are provided in the steam line between PSH
& FSH to permit reduction of steam temperature when
necessary and to maintain the temperature at design
values within the limits.
Temperature reduction is accomplished by injecting
spray water into the path of the steam through a nozzle .
The spray water source is from the boiler feed water system.
It is essential that the spray water be chemically pure to
avoid contamination of main steam.
E- BURNER
4 nos. of Dual Fuel Burner per boilers are mounted on
common windbox . The windbox is designed in such a
manner that combustion air is uniformly distributed to
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all the burners. The combustion air entry to the burner is
through air register which is controlled by pneumatically
operated air cylinder. The dual Fuel Burner is Fitted with
1 No. of oil gun with steam atomiser tip assembly and 8
Nos. of Gas Poker Assembly.
The ignition system which is supplied along with
burner is capable of lighting liquid as well as gaseous fuel
on giving light up command to ignitor . Pilot flame
presence indication will be giving to the Burner
Management System .
In turn BMS will give a signal to open gas valve.
Thereafter Main Gas Flame will be detected by flame
scanners system. The flame scanners system shall provide
the continuous monitoring of the flame inside the furnace
which shall provide safety to the boiler.
In the event of Flame outage of individual burner the
flame monitoring system shall give signal to open or to
close gas valves together with other interlocks for safe
tripping of the burners isolation valves. In the event of all
four burners flame failure it will trip master fuel trip
valve. The flame monitoring system is provided with self
check facility so that spurious signals are eliminated and
reliable performance of the burner is guaranteed.
FD FAN :
Centrifugal Single Suction Fans are being used to handle
Clean Air . The spiral Casing converts part of kinetic
energy of the fluid into a Static Pressure . the Fan output is
usually controlled by adjustable inlet dampers or by
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varying the speed of the Fan either by means of hydraulic
couplings or by any suitable speed control device .The fan
is driven by motor/prime mover through coupling.
OPERATING PROCEDURES FOR BOILER
A - Preparation
1.Inspect the boiler prior to start.
Chack that (a) All foreign material has been removed.
(b) All doors are closed.
( c ) Starting equipments are ready.
(d) Interlocks are OK.
(e) Individual valves of burners are closed.
2.Close the Following Valves.
(a) Feed water regulating valve
(b)All drain valves of boiler, water walls and Economizer.
(c)Desuperheater control valves.
Open the Following Valves.
(a) Drum Air Vents.
(b)SH Air Vents.
(c)SH drain Valves
(d)Main steam line drain valve.
(e)Start up vent valve.
(f)Isolation valves on both sides of desuperheater
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control valve.
(g)All instrument and control connections to the boiler.
3.Check the Following Eqts for adequate Lubrication &
Cooling Water Flow.
(a)Boiler Feed Pump.
(b)FD Fan.
1. Put all automatic Control equipments on Manual
Control.
2. Check that all Control equipments are ready for service.
Manually operate all sequential trips and see that the
emergency fuel trips function properly.
B- LIGHT UP.
a) Take water into Steam Drum and maintain
Drum Level Normal.
b) Close Inlet vanes of FD Fan.
c) Open inlet damper of Air duct.
d) Open inlet damper of Chimney .
e) Start FD Fan.
f) Increase Air Flow more than 30% of MCR.
g) Light the Lower burner one at a time .
h)Close Drum Air vents when Drum pressure reaches 2
Kg/Cm2
.
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i) Take other Burners in line and raise the drum
pressure slowly as per start up curve
j) Connect the boiler with the Header when steam
pressure is 105 kg/Cm2
.
k) Close main steam drain and SH drains.
l) Inject Chemicals into D/A and drum to maintain
C- SHUT- DOWN
a) Start reducing boiler load gradually. Reduce the
firing rate in line with reducing the steam flow.
b) Shut-Down the Burners one at a time, Starting with
the upper elevation .
c) All fires should be out when the boiler is off the line.
d) Run the Fans for at least 10 minutes after
Shutting down.
e) Maintain the water level in drum .
f) When the drum pressure comes down to 2 Kg/Cm2.
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STEAM TURBINE
A turbine is a rotary engine that extracts energy from a
fluid flow and converts it into useful work. The simplest
turbines have one moving part, a rotor assembly, which is
a shaft or drum with blades attached. Moving fluid acts
on the blades, or the blades react to the flow, so that they
move and impart rotational energy to the rotor. Early
turbine examples are windmills and water wheels.
Gas, steam, and water turbines usually have a casing
around the blades that contains and controls the working
fluid. Credit for invention of the steam turbine is given
both to the British Engineer Sir Charles Parsons (1854–
1931), for invention of the reaction turbine and to
Swedish Engineer Gustaf de Laval (1845–1913), for
invention of the impulse turbine. Modern steam turbines
frequently employ both reaction and impulse in the same
unit, typically varying the degree of reaction and impulse
from the blade root to its periphery.
A steam turbine is a mechanical device that extracts
thermal energy from pressurized steam, and converts it
into rotary motion. It has almost completely replaced the
reciprocating piston steam engine primarily because of its
greater thermal efficiency and higher power-to-weight
ratio. The steam turbine is a form of heat engine that
derives much of its improvement in thermodynamic
efficiency through the use of multiple stages in the
expansion of the steam, which results in a closer approach
to the ideal reversible process. There are several
classifications for modern steam turbine.
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Type of Turbines-
(A)Based on operation
Impulse Turbines: It has fixed nozzles that orient the
steam flow into high speed jets. These jets contain
significant kinetic energy, which the rotor blades,
convert into shaft rotation as the steam jet changes
direction. A pressure drop occurs across only the
stationary blades, with a net increase in steam
velocity across the stage. As the steam flows through
the nozzle its pressure falls from inlet pressure to the
exit pressure (atmospheric pressure, or more usually,
the condenser vacuum). Due to this higher ratio of
expansion of steam in the nozzle the steam leaves the
nozzle with a very high velocity. The steam leaving
the moving blades is a large portion of the maximum
velocity of the steam when leaving the nozzle. The loss
of energy due to this higher exit velocity is commonly
called the "carry over velocity" or "leaving.
Reaction Turbines: In this the rotor blades themselves
are arranged to form convergent nozzles. This type of
turbine makes use of the reaction force produced as
the steam accelerates through the nozzles formed by
the rotor. Steam is directed onto the rotor by the fixed
vanes of the stator. It leaves the stator as a jet that
fills the entire circumference of the rotor. The steam
then changes direction and increases its speed
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relative to the speed of the blades. A pressure drop
occurs across both the stator and the rotor, with steam
accelerating through the stator and decelerating
through the rotor, with no net change in steam
velocity across the stage but with a decrease in both
pressure and temperature, reflecting the work
performed in the driving of the rotor.
(B)Based on Steam Supply and Exhaust Conditions
Noncondensing or backpressure turbines are most
widely used for process steam applications. The
exhaust pressure is controlled by a regulating valve to
suit the needs of the process steam pressure.
Condensing turbines exhaust steam is in a partially
condensed state, typically of a quality near 90%, at a
pressure well below atmospheric to a condenser.
In a reheat turbine, steam flow exits from a high
pressure section of the turbine and is returned to the
boiler where additional superheat is added. The
steam then goes back into an intermediate pressure
section of the turbine and continues its expansion.
In an extracting type turbine, steam is released from
various stages of the turbine, and used for industrial
process needs or sent to boiler feedwater heaters to
improve overall cycle efficiency. Extraction flows may
be controlled with a valve, or left uncontrolled.
Induction turbines introduce low pressure steam at
an intermediate stage to produce additional power.
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Principle of Operation
The motive power in a steam turbine is obtained by
the rate of change in momentum of a high velocity jet of
steam impinging on a curved blade which is free to rotate.
This jet of steam impinges on the moving vanes or blades,
mounted on a shaft. Here it undergoes a change of
direction of motion which gives rise to a change in
momentum and therefore a force. The interior of a turbine
comprises several sets of blades. One set of stationary
blades is connected to the casing and one set of rotating
blades is connected to the shaft. The sets intermesh with
certain minimum clearances, with the size and
configuration of sets varying to efficiently exploit the
expansion of steam at each stage.
Operation and Maintenance
When warming up a steam turbine in order to avoid
slugging nozzles and blades inside the turbine with
condensate on start-up which can break these components
from impact. The blades were designed to handle steam,
not water. The main steam stop valves have a bypass line to
allow superheated steam to slowly bypass the valve and
proceed to heat up the lines in the system along with the
steam turbine..
Steam Turbine Components
The components of Steam Turbine are:
Blades
Rotors
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Casings
Seals
Nozzles.
Steam turbines consist of circularly distributed stationary
blades called nozzles which direct steam on to rotating
blades or buckets mounted radially on a rotating wheel.
In a steam turbine nozzles apply supersonic steam to a
curved blade. The blade whips the steam back in the
opposite direction, simultaneously allowing the steam to
expand a bit.Typically, the blades are short in proportion
to the radius of the wheel, and the nozzles are
approximately rectangular in cross section.
STEAM TURBINE GENERATOR (STG # 1)
Vendor : M/s BHEL Hyderabad.
Type : EHNG 40/32 – 3.
Capacity : 15.5 MW.
No. of Stages : 17
HP (Impulse +Reaction) : 1 + 6
LP (Impulse +Reaction) : 1 + 9
Turbine Speed : 8500 rpm.
Reduction Gear Output Speed 3000 rpm.
Steam Pressure : 105 Kg/Cm2
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Steam Temperature : 500 o
C
Wheel Chamber : 75.8 Kg/Cm2
Extraction Pressure : 41.0 Kg/Cm2
Extraction Flow : 55 TPH
Exhaust Pressure : 5.00 Kg/Cm2
Exhaust Flow : 75 TPH
Maxm
Steam Flow : 130 TPH
STG # 2
Vender : M/s BHEL
Type : Full Condensing
Capacity : 25.6 MW
No. of Stages : 48
Impulse : 1
Reaction : 47
Turbine Speed : 3000 rpm
Steam Pressure : 105 Kg/Cm2
Steam Temperature : 500 o
C
Steam Flow : 91 TPH (for full Load)
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POWER GENERATION THROUGH STGs-
Presently the Maximum requirement of Electrical power for
the complex is around 32 MW.
This demand of 32 MW power requirement in met by 2
Steam Turbo Generators .
2 Nos. of Generators having capacity of 15.5 MW & 25.6 MW
are separately coupled with steam turbines, serving as
prime movers.
Power Generated by these Generators is at 11 KV . It is
further stepped up to 33 KV through transformers which is
synchronised with the 33 KV grid.
This power at 33 KV is then stepped down through the
transformers to 6.6 KV & 415 KV to run HT motors and L.T.
motors of the complex.
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&
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DESCRIPTION OF HDPE PROCESS BRIEF
Catalyst system
To initiate any polymerization reaction, catalyst is
necessary. The catalyst system for Polyethylene is based on
„Ziegler-Natta catalysts‟. This system consists of a catalyst-
co catalyst pair. Main catalyst - Halides or other
derivatives of transition metals in group IV-VIII of
periodic table. (In our plant it is the PZ catalyst which is
based on ticl4). Co catalyst - Alkyls of Group I-III metals.
(In our plant it is TEAL i.e. Try Ethyl Aluminum)
Polymerization :
Raw materials
The raw materials used in the production of HDPE and
their roles is as,
Ethylene – This is the basic monomer which forms the
backbone of HDPE chain.
Catalyst – This initiates the polymerization reaction.
Hydrogen – This helps in termination of polymer chain.
Hence this controls the molecular weight. So Hydrogen is
used to control MFR. The control of Hydrogen feed is done
based on Hydrogen / Ethylene ratio. This ratio varies as
per grade because each grade has different MFR.
Butene-1 / Propylene – These two are co-monomers. They
take part in reaction along with Ethylene and form side
branches. The loading of co-monomer decides density of
polymer.
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Hexane – This is inert reaction medium. This helps in
removal of enormous amount of heat of polymerization.
Operation
The polymerization reaction is highly exothermic. It gives
out enormous amount of heat. This heat needs to be taken
out immediately and effectively to avoid run away
reactions. The reactors have three modes of heat removal,
Overhead coolers – the un-reacted gas from reactor is
taken to overhead cooler. The hexane content in the gas is
cooled and separated. The cooled gas is again bubbled
from the bottom of the reactor. Along with agitators, this
helps in preventing the slurry from settling. The condensed
hexane is also fed back to the reactor. Slurry coolers – at
high loads, some portion of slurry is also taken out from
the bottom of the reactors. It is circulated through coolers
and fed back to the reactors. Jackets - Each reactor has
jacket with cooling water running through it.
Feed of Hydrogen to the reactor is most critical part of the
polymerization. It needs to be accurately controlled. Each
reactor is equipped with on line Process Gas
Chromatographs (PGC) for this purpose. A small sample of
un-reacted gas from the reactor is continuously fed to the
PGC.
PGC analyses the Hydrogen and Ethylene content of the
stream. Special programs on the MAPS convert the % to
ratio of Hydrogen to Ethylene.
Hydrogen valve opening is controlled by MAPS Programme
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Separation
The polymer slurry, after degassing, is fed to the
centrifuge. The centrifuge separates the polymer powder
from hexane. The wet cake of polymer is fed to dryer. The
hexane decanted contains some amount of low polymer
formed during polymerization and is called mother
liquor. The wet cake is dried in rotary dryer. Some portion
of the mother liquor is recycled back to the reactors.
Remaining mother liquor is sent to hexane recovery
section of purification of hexane.
Drying
The wet cake from centrifuge is fed to rotary dryer. It has
hexane content of 30% by weight. $Dryer uses two drying
media, Low pressure steam running through the inner pipe
inside the dryer. This is indirect heating. Hot nitrogen fed
to the dryer coming in contact with powder. This is direct
heating. $The hot nitrogen coming from dryer is cooled
and scrubbed with hexane to wash off any entrained
powder. It is again heated and fed back to dryer. The dry
powder (with hexane content of 0.2% wt or lower) is
conveyed to hopper by nitrogen.
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Extruder
The dry powder from dryer is taken to a intermediate
hopper. Before sending to extruder, various additives are
mixed with the powder. The blend of powder and additives
is melted in the extruder barrel. The melt is forced
through a die having number of holes to give thin noodle
like strands. A cutter assembly, rotating very close to the
face of the die, cuts the strands to pellets. The pellets are
conveying by air to various storing silos. From silos, the
pellets are sent for bagging
Hexane recovery
The mother liquor decanted from centrifuge is fed to this
section. The low polymer in mother liquor is separated in a
stripper. Pure hexane vapors from stripper top are
recovered, condensed and dehydrated. The pure hexane is
stored in tanks and put in re-use. The low polymer
concentrate recovered from stripper bottom is subjected to
flashing to recover maximum hexane from it. The low
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polymer is then dumped to pits. After solidification, low
polymer blocks are cut out. These are processed in flaker
plant to form flakes.
Utilities
Various utilities / auxiliary services used in the plant are,
Brine system
HP steam
LP steam
Nitrogen
Process water
Instrument air
Cooling water
Electric power
Caustic soda
MECHANICAL SEAL-
General Classifications
Seals may be generally sub-divided into :
(A)Dynamic Seals
(B)Static Seals
The primary purpose of seals is to prevent ingress of
unwanted contaminants and to prevent egress of any
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internal sustance whether it be gas or liquid for
containment or lubrication. The majority of applications
are in areas where the substance retained is a lubricant
and the purpose of the seal is to ensure that it stays where
it is put.
In simple terms, external seals have two main functions: to
prevent lubricating oil from leaking out, and, to prevent
dust, water, and other contaminants from entering the
bearing. When selecting a seal, the following factors need
to be taken into consideration: the type of lubricant (oil
or grease), seal peripheral speed, shaft fitting errors, space
limitations, seal friction and resultant heat increase, and
cost.
Dynamic seals can be used with either rotary or
reciprocating motions. A separate group of dynamic seals
comes under the heading “others”. These seals are indeed
statistically attached to the counterfaces and the limited
motion is fully taken up by the seal material itself.
Examples of the latter would be bellows and the
diaphragms.
Apart from Static and dynamic, the Sealing devices for
rolling bearings fall into two main classifications:
(a)Contact Seals.
(b)Non-contact Seals.
Contact seals:
Contact seals accomplish their sealing action through the
contact pressure of a resilient part of the seal (the lip is
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often made of synthetic rubber) and the sealing surface.
Contact seals are generally far superior to non-contact
seals in sealing efficiency, although their friction torque
and temperature rise coefficients are higher.
Non-contact seals:
Non-contact seals utilize a small clearance between the
shaft and the housing cover. Therefore friction is
negligible, making them suitable for high speed
applications.
Polymer formation diagram-
Catalyst
preparation
Polymerization
Separation &
Drying
Pelletizer
Hexane
recovery
Low polymer
handling
Flaker unit
Catalyst
(PZ, AT)
Catalyst soln
Raw material like C2,
H2, Bu-1, Propylene
Polymer slurry
Mother
liquor
Mother
liquor
recycle
Dry powder
Pure and dry
hexane
Crude hexane
from IOP
LP pits
LP wax to flaker
LP Flakes
G-Lex pellets for bagging
Molten wax
Recovered
hexane
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LLDPE
REACTION AREA
Solvent (SH) is recycled to the reaction area from the
reflux drum of the HB Column in the Solvent Recovery
Area. The temperature of this solvent stream is
approximately 175o
C and is cooled to 31o
C by a series of
heat exchangers which includes the Process Exchanger
and the Recycle Coolers. First, cooling in the Process
Exchanger will reduce the recycle solvent temperature to
approximately 155o
C. The heat from this stream is used to
warm the feed to one of the distillation columns thereby
increasing the energy efficiency of the operation. Further
cooling is provided with a Recycle SH Air Cooler in series
with a Recycle SH water Cooler. The use of Recycle SH Air
Cooler minimizes cooling water demand.
There are two reactor modes which are normally used.
1) #1 Reactor mode
2) 3→1 Reactor mode
The polymerization reaction is highly exothermic,
releasing approximately 93.7 MJ of heat per kg mol of
monomer or comonomer reacted. All reactor modes
operate adiabatically and therefore there is a substantial
increase in the temperature of the reaction mixtures
through the reactor system.
RECYCLE AREA
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The solvent and steam condensed in the Solvent
Vapour Condenser from the overhead of the Stripper is
collected in a Decanter. In order to facilitate water
removal from the solvent, the Decanter is designed with a
coalescer. Solvent leaving the Decanter is relatively dry,
containing dissolved water but no separate liquid water
phase. The saturation level for water in SH at 35oC is
about 100 ppm by weight. This stream is pumped to the LPS
Hold Up Tank (HUT) in the LPVR area.
Polymer formation flow diagram –
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EXTRUSION \FINISHING AREA
Polymer from the bottom of the LPS is fed directly into the
feed hopper of the Main Extruder. The function of the Main
Extruder is to pressurize the polymer and feed it to the Melt
Cutter or Pelletizer, which produces uniform pellets of the
polymer.
In the feed section of the Main Extruder, there is a
tendency for gas to build up at the rear of the first
extruder screw flite. On low MI resins, at high screw speeds,
the vapour pocket formed Solid additives can be added to
the main extruder with the aid of the satellite extruder.
The Melt Cutter consists of a die plate on which rotates a
set of knife blades which cut the emerging polymer strands
into uniform sized pellets. A flow of water circulates
through the cutter housing to first quench and then
convey the cut pellets away from the cutter.
From the melt cutter, the pellets are conveyed to a
Delumper that segregates large lumps of polymer into a
waste hopper. Generally, large lumps are produced only
during startup of the extruder/cutter system. The Melt
Cutter consists of a die plate on which rotates a set of knife
blades which cut the emerging polymer strands into
uniform sized pellets.
BUTENE-1
process can be divided into following areas:
1. Catalyst section. 2. Reaction section. 3. Evaporation section.
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4. Distillation section. 5. Storage section.
FLOW DIAGRAM OF BUTENE-1
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&
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GAS SWEETENING UNIT
„Sweetening‟ means removal of acid from gases like H2S &
CO2. The HVJ gas is received from ONGC contains CO2
(5.52% by volume) & H2S (4ppm). The gas forms the
feedstock to the C2-C3 recovery unit where cryogenic
conditions prevail & if the CO2 component of the gas is not
received. It will freeze at such a low temp.
Gas sweetening plant uses DEA (Di Ethanol Amine) as a
solvent for removing CO2 in the natural gas by chemical
absorption.
ABSORPTION SECTION
Natural gas coming from HVJ is treated in two parallel
high pressure absorbers. The gas is fed to the absorber
column at a pressure of 52 kg/cm2 & temp 30 C. This gas is
counter currently treated with DEA solvent (40% by
weight) which is fed from the top of the column. The
absorber column contains 30 valve trays. The treated gas
leaves from top of the column at 45 C & contains less then
50 ppm of CO2.
TREATED GAS WATER WASH & COOLING
The treated gas from absorber column is counter
currently washed with water in water wash column
equipped with ball rings to remove the DEA carried over
the gas. The DEA solution in water is removed from the
bottom of this column & sent
to the rich amine flash drum. The treated gas is cooled to
40 C & leaves the unit at pressure 50 kg/cm2.
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RICH AMINE CIRCUIT:
The rich amine from the absorber bottom & the water wash
column are sent to rich amine flash drum. The rich amine
flash drum is operated at 6.5 kg/cm2 & 70 C. Most of the
hydrocarbons are co-absorbed in DEA solution is removed
in this drum & sorted to the plant fuel gas system.
AMINE REGENERATION:
The rich amine solution from the flash drum enters the
regenerator column through the rich lean amine
exchanger at 110 C. In the regenerator the solvent DEA is
stripped off CO2 using low pressure steam in the column
reboilers. The column has 21 valve trays. The top two trays
are used to minimize DEA carryover with the CO2. This
column operates at 2kg/cm2. The top temp is 97 C & the
temp at the bottom is around 126 C. The lean amine is
withdrawn from bottom of the column & is sent to storage
after being cooled to 45 C in rich lean amine exchanger &
then by cooling water.
Vapors from the top of the regenerators are condensed in
the regenerator overhead condenser & taken in to
Regeneration reflux drum. The uncondensed gases mainly
CO2 are vent to atmosphere at a safe location & the
condensed liquid is pumped back as reflux to the column.
AMINE STORAGE:
The lean amine from regenerator is sent to amine storage
tank from where it is pumped to the absorbers. The amine
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tank is blanketed with N2 to prevent solvent degradation
with O2.
AMINE FILTERATION:
A stream of stored amine solution is continuously sent to
the filteration package by amine filteration pump. DEA
solvent filteration is required to remove all the dissolved
hydrocarbons, scales & solvent degradation products that
can cause corrosion & foaming.
Levels of filteration may be as-
a) Precoat filter consisting of cellulose
b) Activated carbon filter which removes corrosion
products
c) Cartridge filter which removes any carbon particles
ANTIFOAM INJECTION PACKAGE:
Antifoam facilities are provided to overcome foaming
problems in the absorber. The antifoam solution is an
aqueous solution of silicon oil. This is injected to the
suction of amine charge pumps.
AMINE DRAIN RECOVERY:
All the solvent drains are removed in an underground
amine sump pump.
C2/C3 RECOVERY UNIT
C2/C3 Recovery plant has been designed by Engineers
India Limited. In this plant C2/C3 fraction of the feed gas
is recovered under cryogenic conditions by Turbo
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Expander process. The C2/C3 product from this unit forms
the feedstock of the gas cracker unit.
The process comprises of the following section:
FEED GAS COMPRESSION:
The sweetened gas is recovered from the Gas Sweetening
Unit at 50 kg/cm2 and 40 C in the field gas Knock Out
Drum where the entrapped liquids are removed. The gas is
now compressed to 55 kg/cm2 in feed gas Expander
compressor.
FEED GAS DRYING/REGENERATION:
The compressed gas is cooled down to 37 C using cooling
water in Feed Gas Compressor discharge cooler and further
down to 18 C by the outgoing lean gas in the feed/lean gas
exchanger. The condensed moisture from the gas is
removed in moisture separator. The gas is now saturated
with water that is removed in a dryer to a water dw point
of -100 C using molecular sieves as desiccants.
There are two dryers out of which one is in drying
mode and the other is either a standby or in regeneration
mode. The drying period is around 12 hours and the
regeneration is also 12 hours.
A part of the lean gas from the first stage discharge of the
lean gas compressors is heated to 320 C in a gas fired
heater and this hot gas is used for regeneration of the
dryers.
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FEED GAS CHILLING/SEPARATION:
The feed gas enters the feed gas chiller #1 where it is
cooled down to -32 C by the separator 1 & 2 liquids and
the lean gas. The gas is further chilled down to -38 C in
the demethaniser side reboiler.
The gas is again chilled in feed gas chiller 1 to about -
55 C to -60 C. The partially condensed feed gas at this
stage is taken to the separator 1 where the condensed
liquid is separated and sent to chiller 1 for cold recovery.
The liquid is then fed to the demethaniser column.
The uncondensed vapor from the separator 1 are cooled
to -18 C by the outgoing lean gas in feed gas chiller 2.
These vapours are now taken to Separator 2 where again
the condensed liquid is separated. Cold from this liquid is
recovered in feed gas chiller 1. It is then mixed with the
Separator 1 liquid and this is fed to the demethaniser
column on tray 18.
FEED GAS EXPANSION:
The overhead gas from separator-2 is expanded
entropically in the feed gas expander to around 22
kg/cm2 and the temp of the gas drops to -98 C. Due to this
chilling, there is further condensation of the gas. This
vapour liquid mixture is fed to the demethaniser column
on the 8th
day .The work available from the isentropic
expansion of the Separator-2 vapour is used to compress
the feed gas.
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FRACTIONATION:
The reaction consists of a demethaniser column which
serves to recover C2-C3 product from (i) Separator 1 & 2
liquids received at -68 C and (ii) feed gas expander
overhead vapours received at -98 C.
This separates almost all the methane from the gas. It
consists of 36 valve trays and one chimney tray for
supplying feed to side reboiler. The column reboilers chill
down the feed gas and in turn recover reboiler duty. The
overhead vapours are chilled from -98 C to -102 C and
condensed in the demethaniser overhead condenser by the
cold gas from the demethaniser over expander outlet -117
C. The demethaniser overhead vapour is expanded from
21.5 kg/cm2 to 12 kg/cm2 and due to this gas is chilled to
-117 C. This cold methane is the major source of
refrigeration in the unit.The bottom product from the
demethaniser column is the C2/C3 product, which is
pumped as feed to cracker unit or sent to storage. The
recovery of C2 is around 90%.
LEAN GAS COMPRESSION:
The lean gas after giving away its cold to a series of
exchanger (viz. Feed Gas Chiller-2, Feed Gas Chiller-1,
Feed/Lean Gas Exchanger) gets heated to 25 to 30 C and is
first compressed from 10kg/cm2 in the demethaniser
overhead expander compressor and is further compressed
to 55 kg/cm2 in a 2-stage gas turbine driven Lean Gas
Compressor. It is cooled to 40 C and then sent back to HVJ
pipeline. About 36 ton/hr of lean gas is drawn from first
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stage discharge of the lean gas compressor for dryer
regeneration. This gas is then compressed to 55 kg/cm2 in
a steam turbine driven Residue Gas Compressor and is
then sent to Lean Gas Compressor discharge header.
A part of gas from the first stage Lean Gas Compressor
discharge is also taken for internal fuel consumption of
the unit.
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GAS CRACKER UNIT(GCU)
The Gas cracker unit is a part of the U.P.Petrochemical
complex. The Gas Cracker unit comprises of the Hot section
(cracking furnace /cracked gas compressor) and Cold
section (The Ethylene recovery unit). The C2/C3
hydrocarbon is cracked and compressed in Hot section
and Ethylene, Hydrogen, Propylene, C4mix, C5+ are
separated (distilled) in Cold section. Ethylene and
Hydrogen are main product, where as Propylene, C4 mix
and C5+ are separated as by products. The waste heat from
the cracker gas effluent is used to produce VHP steam at
105 Kg/cm2 and 510O
C, which is subsequently used for
running the turbine of gas compressors and heat
requirement of the GCU plant.The breaking of molecule to
yield more useful products is called cracking. Cracking
requires high temperature to initiate it and is
endothermic. The heat is supplied by the direct firing of
fuel gas in the furnace.
Gas cracker Plant mainly consist of following units
a) Furnace/ Quench Tower
b) Cracked Gas drying
c) Dispersed Oil Extraction process.
d) Demethaniser
e) Hydrogen unit (PSA)
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f) De-ethaniser
g) C2 Hydrogenation
h)Ethylene Tower
i) Ethylene Product Distribution
j) DeButaniser
k) Propylene Stripper
FURNACES
The pyrolysis furnace area consists of four 24 W 144 type
furnaces for 300,000 MTA ethylene capacity based on 8000
hours / year. The furnaces are both wall and floor fired
and utilize gas fuels.As off-set connection section recovers
waste heat from the flue gases leaving the radiant section
of the furnaces. The fire gases are finally discharged to
atmosphere via an induced draft fan and a stub stack.
The cracked gases leaving the radiant coils are quenched
in a series of exchangers before being routed to the quench
water tower.
The convection section of the pyrolysis furnaces contains
the following services:
a) Hydrocarbon (HC) Preheat - I.
b) Boiler Feed Water (BFW) Economizer.
c) HC Preheat II
d) High Pressure Superheated Steam (HPSS).
Hydrocarbon + Dilution Steam (HC + DS).
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Process Description
FEED VAPORIZATION:
C2/C3is received from C2/C3 recovery unit of GPU at 0 C
and 22 kg/cm2 abs. It is flashed to around 10 kg/cm2 abs
whereby it gets cooled at -26 C. It is then first heated by the
propylene refrigerant and then by quench water and LP
steam to around 80 C.
CRACKER FURNACE:
Dilution steam is mixed with C2/C3 vapor in the ratio of
0.3:1 and fed to convection section of furnace.
The dilution steam has two functions:
a) Reduce the hydrocarbon partial pressure thereby
increasing yield of ethylene.
b) Reduce the rate of coke formation thereby increasing
the furnace run length.
In the convection section of furnace the feed gets heated to
around 650 C by heat exchange with fuel gas. It is then
fed to the radiant section of furnace where cracking of
C2/C3 takes place. There are 5 furnaces each having
capacity of 1,00,00 TPA. Each furnace has 12 W type
radiant coils having total length of 44m. The
temperature at the exit of the radiant coil is 850 C. the
conversion per pass for ethane is around 75% by weight
while that for propane is 93%. The hot gases are cooled to
around 350 C by generating VHP steam in USX and TLX
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exchangers. It is further cooled to around 200 C in TLX-2
by heating boiler feed water.USX and TLX are heat
exchangers.
QUENCH WATER AND DILUTION STEAM:
The hot gases are then quenched and cooled to around 40
C by direct contact with water in quench tower. Some light
fuel oil present in cracked gas gets condensed. This is
separated from water in oil water separator and pumped
to off sites. The steam, which gets condensed in quench
tower, is pumped to process water treatment unit to remove
impurities such as oil and suspended solids. The treated
water is pumped to dilution steam is generated and used
in the process.
CRACKED GAS COMPRESSION & DEHYDRATION:
The cooled cracked gas is compressed from 1.4 kg/cm2 abs
to 26 kg/cm2 abs in a 4-stage steam turbine driven
compressor having rated power of 18 MW. Inter stage/after
stage coolers and KOD are provided to cool the compressed
gas and separate the condensed liquid (fuel oil). H2S and
CO2 present in cracked gas are removed in caustic tower
between 3rd
and 4th
stages of compression. The cracked gas
after the 4th
stage is cooled by cooling water and propylene
refrigerant and
then routed to dehydrators where the moisture in cracked
gas is reduced to <1ppm by volume
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DEMETHANISER:
The dried gas is cooled in demethaniser section to around
-100 C by different levels of propylene and ethylene
refrigeration. It is further cooled to -135 C by vapors from
expander compressor. The condensed liquids are
fractioned in demethaniser system. The C2+ liquids are
sent to deethaniser while the vapors (mainly CH4 and H2)
are routed to expander where they are expanded from 21
kg/cm2 abs in a 3-stage machine. The vapors after giving
cold in demethaniser section are compressed and routed
to fuel gas system.
The polybed Pressure Swing Adsorption (PSA) unit for
hydrogen purification is designed to deliver a constant
and continuous flow of high purity hydrogen product
stream. PSA employs molecular sieve type adsorbent to
purify the crude hydrogen stream supplied from
demethaniser system. The adsorber operates on an
alternating cycle of adsorption and regeneration with
adequate beds always available for service.
ETHYLENE RECOVERY UNIT:
In deethaniser, ethane/ethylene mixture gets separated
from C3+. The ethane/ethylene mixture (top product from
deethaniser) is fed to C2 hydrogenation section where
acetylene is converted to ethylene/ethane by
hydrogenation using palladium catalyst. The affluent
from C2 hydrogenation is routed to green oil tower where
green oil is removed by washing with cold ethylene. The
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overhead from green oil tower after passing through
secondary
dehydrator is fractioned in ethylene tower to separate
ethylene and ethane. Ethylene tower has 116 trays and
operates at a pressure of around 18 kg/cm2 abs to produce
ethylene product of 99.8% by mole. A part of the ethylene
(5%) is cooled and sent to cryogenic storage. From the
remaining 95% ethylene, cold is recovered before sending
it to downstream plant. The ethylene tower bottom supplies
the ethane recycled to the cracking furnace.
PROPYLENE RECOVERY:
The bottom of the deethaniser is sent to depropaniser,
which operates at 7.2 kg/cm2. In depropaniser, propane
and propylene are recovered in mixture form. The
propane/propylene mixture from the top of the
depropaniser is fed to C3 hydrogenation system where
methyl acetylene propadiene is converted to
propane/propylene. The reaction takes place at temp 9-44 C
and pressure of 16.4-17.4 kg/cm2 in C3 hydrogenation
system. The propane/propylene mixture is then fractioned
in propylene tower to give chemical grade propylene as top
product and propane as bottom product. Propylene tower is
maintained at a pressure of around 18 kg/cm2 and has
109 trays. The propane is recycled back to furnace.
BUTANE RECOVERY:
The bottom product from depropaniser is routed to
debutaniser, which operates at 4 kg/cm2. The overhead
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product is C4 fractions and bottom product contains C5
and heavier materials, which is sent to battery limit.
REFRIGERATION:
The plant has a 4-stage propylene refrigeration and 4-
stage ethylene refrigeration. Propylene refrigerant
compressor is designed to supply propylene refrigerant at -
38.9 C, -24.4 C, -5.6 C and 7.2 C. The compressor is driven
by condensing steam turbine. Ethylene refrigerant
compressor is designed to supply ethylene refrigerant at
four levels 100.6 C, -84.4 C, -67.8 C and -48.3 C respectively.
The compressor is driven by a condensing steam turbine.
PROPYLENE REFRIGERATION SYSTEM
The Propylene refrigeration system will be put in normal
operation as the first one of the three main compressors.
C3R system will be utilized for cool down of the
Demethanizer and it will be the single source of process
refrigeration until C2R system start up. Propylene
refrigeration system provides the initial chilling of gases
down to –38.90
C. Propylene refrigerant at different pressure
pickup the heat from other streams generating propylene
vapors at different pressures. Propylene refrigeration
compressor compresses these vapors with discharge pressure
of 17.5 kg/cm2, at which the propylene is condensed using
cooling water. The liquid propylene is then flashed back,
to provide chilling down to –39.2 0
C in the circuit.
REFRIGERATION SYSTEM IN GCU
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To get the desired products and by products of required
purities from furnace effluents, it is required to be passed
through a series of distillation columns after cracked gas
is compressed and chilled adequately. The chilling is
achieved by refrigeration system.
Refrigeration system in GCU consists of Propylene
refrigeration system (C3R) and Ethylene refrigeration
system (C2R). C3R compressor is driven by backpressure
cum condensing type turbine running using 105 kg/cm2g
steam. C2R compressor is driven by condensing type
turbine using 40 kg/cm2g steam.
Four modes of operation for each of the refrigeration
compressors were studied by the licensor SWEC. There are 2
different feed cases, referred to as Case 1 and Case2.There
are 2 different chilled liquid ethylene product rates
referred to as Case A and Case B. These two chilled liquid
ethylene product rates are 24000TPA and 155000TPA
respectively.
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LPG UNIT
The objective of this unit is to recover Liquefied Petroleum
Gas (LPG) and propane from Natural Gas (NG) and to
provide C2/C3 feed stock to the existing Gas Cracker Unit
(GCU).
PROCESS DESCRIPTION:
Feed from GPU is fed at the 6th
tray of C2/C3 column having
36 valve trays. Column is operated at a pressure of 22
kg/cm2. The column is designed to operate at a temp of 7.7
C at the top and 82.3 C at the bottom. Column top product
is mainly C2, C3 and some percentage of C4 at a temp of -3
C which is transferred to C2/C3 storage or GCU by C2/C3
reflux and transfer pump and bottom product is C3+ which
goes into LPG column for further fractionation. Top
product C2/C3 vapor from C2/C3 column is condensed in
the condenser by propylene refrigerant.
LPG COLUMN:
Bottom product C3+ from C2/C3 column is fed at 14th
tray
of LPG column having 54 valve trays. Column is operated
at temp of 150 C and 15.5 kg/cm2. Temp at the top and
bottom of column are 58 C and 130 C respectively.
Operating pressure is 11 kg/cm2. Top product of the
column is LPG vapor (C3, C4 and some C5), which goes into
condenser where it is condensed by cooling water, which is
being circulated in tubes. LPG product at 45 C is pumped
to the LPG storage bullets by reflux and transfer pumps.
Heat load is provided by MP steam at 16 kg/cm2. Now,
bottom product goes into pentane column.
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PENTANE COLUMN:
In pentane column, pentane and Spatial Boiling Point
Solvent (SBPS) are recovered. Feed enters at 15th
tray of
column having 19 valve trays. Column is designed for a
temp of 85 C and a pressure of 16.8 kg/cm2. It is normally
operated at a temp of 42 C at the top and 66 C at bottom
and a pressure of 14.2 kg/cm2. Top product of column is
pentane vapor which goes into condenser where it is
condensed by cooling water and then it is stored in the
storage tank and part of condensed pentane is used as
reflux in the column. Bottom product is SBPS, which is like
petrol. Head load is provided by LP steam at 5 kg/cm2.
PROPYLENE REFRIGERATION SYSTEM:
PRS has been provided in order to take care of chilling in
LPG unit. Turbine, which is driven by VHP steam, produces
MP steam & LP steam. MP steam is used in LPG bottom
reboiler and LP steam is used in bottom reboiler of C2/C3
and of propane column. Mechanical work produced in this
process is used to run compressor. Propylene liquid is used
as cooling medium in C2/C3 over head condenser to
condense the C2/C3 vapor. Propylene gets vaporized
during the condensation process. Propylene vapor is fed to
the Knock Out Drum (KOD-3). From KOD-3, it is fed to the
suction of compressor at 4.8 kg/cm2 and -7.0 C and
remaining propylene liquid is pumped into evaporator
where it is converted into vapor and then transferred to
KOD-2 and some liquid which is not vaporized goes into
evaporator where it is converted into vapor and this vapor
is fed to KOD-1. Vapor from KOD-1 at 1.4 kg/cm2 and -41 C
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is feed for suction-1 and it comes out from discharge-1
and D-1 goes into S-2 along with feed at 2.3 kg/cm2 and -
28 C coming from KOD-2. This compressed feed comes from
D-2 and goes into S-3 along with the feed from KOD-3.
Now this compressed vapor coming out from D-3 is routed
to S-4 along with vapor at 8.7 kg/cm2 and 13 C from KOD-
4. Final discharge from compressor is routed to condenser
where propylene vapor is condensed by cooling water and
then it is fed into accumulator at 40 C and 16.9 kg/cm2.
From accumulator, it is routed to KOD-4 and then it is
sent back to the C2/C3 condenser. Make up refrigerant is
also provided because of loss in propylene during
operation. Antisurge valves are provided to each KOD to
avoid back flow.
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GAIL is the only HDPE/LLDPE plant operating in Northern
India and has a dominant market share in North India.
The primary thrust markets for the polymers had been
Western India, but, with the entry of GAIL in the HDPE &
LLDPE market Verticals, today North India has also
witnessed a rapid and significant growth in the polymer
downstream processing Verticals. In a successful span of
about a decades of establishing and marketing its grades
under the brand names G-Lex & G-Lene, GAIL has along
side augmented its name plate capacity of HDPE & LLDPE
to 4,10,000 MTPA by adding another dedicated HDPE
downstream polymerization unit of 1,00,000 MTPA.
GAIL has two trains of dedicated HDPE units of the Mitsui
slurry technology license (capacity 2 x 1,00,000 MT/A) and
marketing the grades under the brand name of G-lex and
one train of the HDPE/LLDPE swing plant under the
Novacor solution based technology license (capacity
2,10,000 MT/A).
Further by adding 6th furnace & de-bottlenecking of the
plant, the GAIL‟s Pata plant capacity will reach to 5,00,000
MTs of Ethylene & 5,00,000 MTs of HDPE/LLDPE producing
capacity by FY 2011-12.
The petrochemicals business of GAIL has consistently
achieving all set targets with respect to its production and
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sales all through-out.
GAIL has also formed a Joint venture company by the
name of M/s Bhramaputra Cracker and Petrochemicals
Ltd. (BCPL) to accelerate the GoI‟s only authorized
petrochemical project in the North East of India (at
Lepetkata, Assam, India). The BCPL is a JV between the
Government of Assam, GAIL(I) Ltd., OIL (India) Ltd. &
NRL.
Further, GAIL has plans to augment the installed capacity
further by putting up new plants of HDPE/LLDPE by 500 KTA
at Pata, which is targeted to be operational by FY 2013-14.
References :
Contents from the library of GAIL(India) Ltd. Pata
www.wikipedia.org/wiki/GAIL
www.gail.nic.in