Download - CDU VDU Operation
PRESENTATION ON
OPERATION OF CRUDE AND VACUUM
DISTILATION UNIT
By: SK. M.RAHMANGM- Operation
Crude Distillation UnitCrude Distillation Unit
ObjectiveTo separate crude into different products by
boiling point differences. Prepare feed for secondary processing units
Key FeaturesTwo kerosene draw-off flexibility to meet
changing market and product specifications. Heavy gas oil (HGO) draw off minimizes load
on Vacuum Heater and Vacuum columnOver flash facility provided in atmospheric
and vacuum column as part of advance process control.
CapacityCapacity
Case - 131500 MT/D - 70/30 Arab Light / Arab Heavy
Case - 231500 MT/D - 50/50 Arab Light / Arab Heavy
Case - 327000 MT/D - Bombay High
Licensor - ABB LUMMUS CREST Ltd. Detailed engineering - ENGINEERS INDIA Ltd
ATMOSPHERIC DISTILATION UNITATMOSPHERIC DISTILATION UNIT
Distillation of Crude Oil to produce :Product Name Cut Range UsageFuel Gas C1 - C2 Internal FuelLPG C3 - C4 Domestic FuelOverhead Naphtha C5 - 120 Feed for NHT/CCRHeavy Naphtha 120 - 140 Diesel ComponentKerosene 140 - 270 Domestic FuelATF 140 - 240 Aviation FuelLight Gas Oil 240/320 Diesel ComponentHeavy Gas Oil 320 - 370 Diesel ComponentReduced Crude Oil 370 - 560+ VDU Feed / IFO
CRUDE SPECIFICATIONCRUDE SPECIFICATION
Properties Case 1 Case 2 Case 3
Specific gravity 60/60 0.864 0.87 0.832
Density at 20oC kg/m3 862 867 830
Sulfur wt% 2.2 2.4 0.17
Pour point Below ambient Below ambient 30 deg C
Viscosity at 20oC cSt 18 24 4.8
Viscosity at 50oC cSt 7.5 9 2.6
Viscosity at 100oC cSt 2.8 3.2 1.3
Nickel ppm wt% 8.4 10.5 1.15
Vanadium ppm wt% 31 38 0.44
CCR value wt% 5.35 6.14 1.29
UOP K 11.89 11.88 11.93
oAPI 32.27 31.14 38.57
B S&W (vol %) 0.5 0.5 0.5
Atmospheric Distillation ProcessAtmospheric Distillation Process
16000 M3X2
Desalter-I Desalter-I
Desalter-II Desalter-II
Preflash
Preflash
Off Gas / Ovhd Naphtha - SGUOff Gas / Ovhd Naphtha - SGU
Heavy Naphtha -NHTHeavy Naphtha -NHT
L Kero - KMU,FOL Kero - KMU,FO
H Kero - KMU, FOH Kero - KMU, FO
LGO -DHDS, FOLGO -DHDS, FO
HGO - DHDS, FOHGO - DHDS, FO
RCO to VDURCO to VDU
3640C3640C
280 0C280 0C
20 0C20 0C
20kg/cm2 g20kg/cm2 g
125 0C125 0C
130 0C130 0C
11kg/cm2 g11kg/cm2 g
Process DescriptionProcess Description
Crude is pumped from day tanks to DesaltersAfter preheating with product streams crude
enters in to Desalters. Two stage desalting is done to remove salts
Salt removal from crude helps in prevention of– Heat exchangers fouling– Corrosion of atm column from hydrolyzing of salts
Desalter outlet is sent to Pre-flash vesselFor removal of lighter fractions
Removal of lighter fractions helps in – Reduction of vapor phase and two phase flow in preheat
exchangers and fired heater– Facilitates higher throughput and optimum equipment
sizing
Pre flashed vapors are directly fed to Atm Column
Process Description…Process Description…
Pre flashed liquid sent for further preheating.Preheating of crude with hot product streams Helps
in Heat optimization Lower loads on fired heaters Lower cooling water requirement for products cooling
Preheated crude comes to Fired HeatersWhere it is further heated to 364 0C
Heated crude finally enters Atm Column. Where it is fractionated as per required
specifications Product streams are sent to storage /
secondary processing
DESALTER OPERATIONDESALTER OPERATION FUNCTION OF DESALTER IS TO REMOVE SALT FROM CRUDE. OPERATING VARIABLES TEMPERATURE : 130 DEG. C OUTLET CRUDE SALT CONTENT : <0.5 ptb PRESSURE: 8-11 kg/cm2 BRINE OIL CONTENT: 165 ppm (max) WATER INJECTION RATE: 4 - 6 % Vol. Of Crude INTERFACE LEVEL: 40 - 50% DEMULSIFIER INJECTION: 6 - 8 ppm on crude
DESALTER - 1 DESALTER - 2
MIXING VALVECRUDE
DEMULSIFIER DEMULSIFIERWATER WATER
PREFLASH VESSELPREFLASH VESSEL
Pre flash vessel helps to remove around 3-4% of lighter ends from the crude and send them to the main fractionating column by-passing the furnace, thus reducing un-necessary furnace load.
Pre flash vessel is also acting as a surge vessel for CDU Heater Feed.
Pre-flashed vapors is introduced in the Crude Column LK section.
PR
EFL
ASH
VESSEL
PV
PRE-FLASHED VAPOURS
PRE-FLASHED CRUDE
DESALTED CRUDE
(3-4% OF CRUDE)
CRUDE HEATERSCRUDE HEATERS
Crude heater 24 burners in each heater. Dual fired burners arranged into 6 groups.
Each group has four burners. Each groups has two pilot flame detectors.
– Pilot flame detractors are arranged on alternate burners.
Two FD fans and one ID fan. MP steam is generated in convection section. 8 Pass flows in each heater.
CRUDE COLUMN OPERATIONCRUDE COLUMN OPERATION
FLASH ZONE : Partially vaporized crude from heater at 364 °C enters the flash zone of the crude column. Here the vapors travel upward and the liquid travel downward. The section of the column below the flash zone is the stripping section and the one above is the rectifying section.
STRIPPING SECTION : Here the liquid traveling downwards is stripped off its lighter components by the stripping steam traveling upwards. There are 6 fixed valve trays in this section.
RECTIFYING SECTION : Here the hydrocarbon vapors traveling upwards are rectified through mass transfer, whereby its heavier components are condensed by the comparatively cold circulating reflux, which travel down and in turn the lighter components of the down-coming liquid are taken up by the hot vapors.
There are 63 nos. valve trays and 6 nos. chimney trays in the rectifying section.
CRUDE COLUMN OPERATIONCRUDE COLUMN OPERATION
REFLUXES : Refluxes serve two purposes - provide liquid in the rectifying section to cause liquid and vapour contact for fractionation - maintain temperature gradient in the column
OVERFLASH : The flashed vapors of the crude which condenses on the first tray above the flash zone are dropped down to the stripping section. This is known as over flash and it helps in (a) stabilizing the bottom product and (b) proper fractionation of Gas Oil. Over flash should be ideally 3-5% of crude vol.
STRIPPING STEAM : This helps in removing the lighter ends from the bottom product by decreasing the partial pressure. It is introduced below the valve trays in the stripping section.
CRUDE COLUMN FLASH ZONECRUDE COLUMN FLASH ZONE
Combined heater outlet enters flash zone.A vane type feed inlet and a large empty space allows
vapor/liquid separation by gravity with minimum entrainment.
Flash zone is large enough to contain foaming.The incoming vapor from the heater produces significant
turbulence – This is controlled by passing the vapor from the flash zone through a
chimney collector tray 69 which also serves as vapor distributor.
Hot Crude
Bottom SectionBottom Section
Liquid from flash zone and gas oil from the collector tray 69 is collected on tray 70Routed to the stripping section.
In the stripping section (trays 70 to 75) hydrocarbon vapors are stripped out from the residue by medium pressure stripping steam injected at the bottom of this section.
Atmospheric residue or Reduced Crude Oil (RCO) is drawn from the bottom Pumped to vacuum Distillation Unit.
Where it is further heated in fired heaters before vacuum distillation process.
Overhead Section..1Overhead Section..1
Two-stage condensation with wash water circulation.First stage condensation
In Crude / overhead exchanger, 10E-102, Then in air fin exchanger, 10EA-301, to 90 0C To avoid corrosion by strong acids
– Wash water is circulated and injected at the inlet of 10E-102.
– Corrosion inhibitors injected in overhead vapor.
After air cooler it is sent to the reflux vessel,10V-301,– For separation of vapor, hydrocarbon liquid and water.
Second Stage Condensation Uncondensed vapor from the reflux vessel is sent to
– Air cooler 10EA-302
– Then to exchanger 10E-301(cooling water) to 40 0C where the overhead naphtha product is condensed .
» The mixed phase this exchanger is sent to naphtha vessel 10V-302.
Neutralizers & corrosion inhibitors are added in vapor line
Neutralizers & corrosion inhibitors are added in vapor line
From the reflux Vessel Naphtha is sent by the reflux pump 10P-302 to
column. Sour water is sent to battery limit
In Naphtha Vessel water, hydrocarbons and uncondensed vapor are
separated. Liquid naphtha sent to the battery limit as overhead
naphtha product. Water, is preheated against the sour water going to battery
limit, and sent back as recycled wash water to the inlet of the overhead exchanger.
uncondensed off gas sent to off gas compressor 10K-301 Compressed to 10 kg/cm2a and sent to saturated gas separation
unit.
Overhead Section…2Overhead Section…2
Col Ovhd Col Ovhd
Air Fin Air Fin Air Fin Air Fin
Exch Exch
OFF Gas COMPOFF Gas COMP
TreatingTreating
Nap ProdNap Prod
Crude Pht
Reflux Vessel
Nap Vessel
Wash WaterWash Water
Overhead CircuitOverhead Circuit
Reflux
Heavy Naphtha section
Fractionation between heavy naphtha and lighter fractions of crude occurs between tray 1 and 11.
Product is drawn from tray 12 to H naphtha stripper, 10C-401 under level control.
In the stripper light components are removed by thermo siphon reboiling against Top Pump Around.Stripper vapors are sent back to column
Product is cooled in air fin cooler followed by CW cooling and sent to storage.
Light kerosene section
Fractionation between Lkero H- naphtha between tray 13 & 24.
Product is drawn from tray 25 to Lkero stripper, 10C-501 under level control.Light components are removed from the light
kerosene by reboiling with LGO PA. Use of steam is avoided for stripping to prevent
presence of water in product
From Stripper it is sent to crude preheat exchangersFollowed by cooling in air fin cooler and CW
cooler.
Cooled product is sent for treatment / storage.
Heavy kerosene Section
Fractionation between Hkero & Lkero between trays 26 & 40.
Drawn from tray 41 to Stripper 10C-601 under Level Control Steam is injected to strip out
lighter components Hkero is pumped with 10P 601 to
10E105 (crude) Then to 10EA 601 air fin cooler and then to Hkero Dryer 10C602
– Dryer vapor outlet is connected to ejector inlet of vacuum column
– Moisture is removed by vacuum Then to 10EA 602 before sending to
storage/treating Storage
HK/Crude
37 Stripper
Air Fin
Dryer
Air Fin
41
Hkero Pump AroundHkero Pump Around
Hkero pumparound is provided from tray 41 to 37.
Medium pressure steam is generated in exchanger 10E-903.
Hkero is then sent to the stabilizer reboiler in the SGU unit
HK PA from SGU is preheat the dry crude in 10E-155 and then it is returned back to the crude column.
TOP Pump AroundTOP Pump Around
Provided from tray 30 to 26. The top pumparound is first
used as heating medium in the heavy naphtha reboiler, 10E-401
Subsequently to preheat crude.
PurposeHeat removal from tower which
helps in Maintaining temperature profile Draw off temperatures and
product quality control
TPA/HNAP TPA/Crude
30
26
LGO Stripping & RundownLGO Stripping & Rundown
Fractionation between LGO/ Hkero in trays 42 & 57.
LGO Drawn from tray 52 to stripper 10C 701 under Level Control 10LV-104Steam is injected to remove lighter fractions
Then pumped to 10E-902 to generate MP steam.
Subsequently sent to LGO/Crude exchanger 10E-109.
Then to cooler 10EA-701 and to 10E-701 trim cooler.
Finally sent to HDS/storage/blending
LGO Pump AroundLGO Pump Around
LGO PA is provided from tray 48 to 52
The duty is utilized to generate MP steam in exchanger 10E-901.
LGO from 10E-901 is sent to the light kerosene reboiler 10E-501, as a heating medium
Finally returned back to the crude column 10C-201.
LGO/LKero
48
52
LGO/MPst
HGO stripper & rundownHGO stripper & rundown
Fractionation between HGO and LGO occur between tray 53 to 58.
HGO product is drawn from tray 63 under level control
After steam stripping product sent to 10E-905 to generate MP steam.
HGO is further cooled in Crude preheat exchanger 10E-108
Finally through air cooler 10EA-801 Product HGO is sent to HDS unit/ storage/ blending.
HGO Pump AroundHGO Pump Around
HGO pump around is provided from tray 59 to 63.
heat is utilized to preheat crude before the furnace in exchanger 10E-153 A/B.
Subsequently HGO is used to generate MP steam in 10E-904
Finally sent back to crude column as pump around.
VACUUM DISTILLATION UNIT
Vacuum Distillation UnitVacuum Distillation Unit
Crude Crude Crude Crude Atmospheric Atmospheric DistillationDistillation
Atmospheric Atmospheric DistillationDistillation
Middle Middle DistillateDistillatess
RCO RCO
TO VDUTO VDUTO VDUTO VDU
BlendingBlending BlendingBlending
Secondary Secondary ProcessingProcessing
Secondary Secondary ProcessingProcessing
StorageStorage StorageStorage
Process Description-1Process Description-1
Feed to vacuum heater is received from atmospheric column bottom Which is further separated
into middle and heavy distillates under vacuum
Feed flow is cascaded with crude column level.
The atmospheric residue feed to the unit is combined with recycle HHVGO and (in case of Bombay high feed) recycle vacuum residue.
The joint feed is sent to heaters 11F-101 A/B.
F-101 A/B F-101 A/B
FC FCLCLC
Recycle HHVGO(AL/AH) / VR
(BH)
Recycle HHVGO(AL/AH) / VR
(BH)
VACUUM HEATERSVACUUM HEATERS
Velocity steam is mixed in the radiant section of heater to start vaporization by lowering hydrocarbon partial
pressure. Here most of the heat is absorbed as heat of vaporization as
opposed to temperature increase. Thus rise in COT temperature is prevented.
It also helps in slowing down coking process
Vacuum heater Sixteen burners in each heater. Dual fired burners arranged into four groups.
Each group has four burners. Each groups has two pilot flame detectors.
– Pilot flame detractors are arranged on alternate burners.
Two FD fans and one ID fan. LP steam is generated in convection section. LP superheater coil is also given to superheat LP steam.
Velocity Steam
Velocity Steam
Vacuum Column-1Vacuum Column-1
Combined heaters outlet goes to vacuum column at 403 0C
Height 50 m Diameter
Top 8.2 m Middle 12.5 m Bottom 6.8 m.
Four structured packed bed.
COT - Coil Outlet Temperature is kept below 420 0C To avoid cracking which
may cause coking and overload vacuum system
50 m50 m
6.8 m6.8 m
12.5 m
12.5 m
8.2 m8.2 m
Flash Zone and Stripping Flash Zone and Stripping
Liquid from flash zone is collected on a chimney tray and passed to the stripping section.
Vapors are passed through chimney tray and packed bed no 4
Light hydrocarbon are stripped on valve trays with superheated LP steam.
Residue is quenched to 360oC with cooled vacuum residue in order to prevent cracking in the bottom section.
FeedFeed
Flash Zone - vane type inlet
Flash Zone - vane type inlet
Stripping Section
Stripping Section
Chimney Tray
Chimney Tray
Bed 4Bed 4
SteamSteam
Valve Trays
Valve Trays
VDU ProductsVDU Products
Vacuum DistillateVacuum Distillate
FEED FEED
LVGO LVGO
HVGOHVGO
HHVGOHHVGO
VRVR
Ejectors and Vacuum PumpEjectors and
Vacuum PumpBED-1BED-1
BED-2BED-2
BED-3BED-3
BED-4BED-4
RefluxReflux
Air Cooled TPAAir Cooled TPA
HVGO - PAHVGO - PA
HVGO - RefluxHVGO - Reflux
Overhead SectionOverhead Section
VDU Overhead
VDU Overhead
Vapor from CDU Dryers
Vapor from CDU Dryers
Ejector PackageEjector
Package
SteamSteam
Condensation and Vapor
Liquid Separation
Condensation and Vapor
Liquid Separation
Vacuum Pump Package
Vacuum Pump Package
UncondensUncondensed vapored vapor
UncondensUncondensed vapored vapor
Vent Gas Seal
Vessel
Vent Gas Seal
Vessel
Water / Slop Oil
Water / Slop Oil
Slop Oil Storage
Sour Water Stripper UnitSour Water
Stripper Unit
Vent Gases incineratedVent Gases incinerated
Vacuum pulling is done with steam ejectors. The load on the ejectors is determined by the overhead vapours, which comprise :
- Non condensibles like cracked gas from furnace and air leaks- Condensible hydrocarbon vapours- Entrainment- Furnace velocity steam- Tower stripping steam
PRESSURE PROFILE ( Not To Scale)
100 psig
DISCHARGENOZZLE
DIFFUSER
SUCTION
MOTIVESTEAM
1.16 psig
0.1 psig
EJECTOR SYSTEMEJECTOR SYSTEM
Ejectors convert pressure energy of motive steam into supersonic velocity from the motive nozzle, thereby creating a low pressure zone for pulling the suction load into the ejector.
OIL WATER
FROM
VAC. COL.
1st Stage 2nd Stage 3rd Stage
HOT WELL
OFF GAS
THEORY OF EJECTOR SYSTEMTHEORY OF EJECTOR SYSTEM
BAROMETRIC LEG : The drain line from condensers to hot well is thebarometric leg. Draining is by gravity, so barometric legs should be high enough to avoid flooding of the condenser tubes. Hot wellpressure is atmospheric. Hence minimum barometric height shouldbe 34ft in case of pure water and 45ft in case of hydrocarbon.Various barometric arrangements are shown below :
HOT WELL HOT WELL HOT WELL
45 deg. (min.)
PREFERRED ACCEPTABLE INCORRECT
THEORY OF EJECTOR SYSTEMTHEORY OF EJECTOR SYSTEM
VACUUM DISTILLATEVACUUM DISTILLATE
StorageStorage
Vac Dist Vess
el
Vac Dist Vess
el
FCFC
TCTC
FCFC Bed 2 Temp is controlled by Vac Dist reflux
This provides desired separation between LVGO and Vac Dist
Part of Vac Dist is cooled at crude preheat train and air fin cooler
Cooled Vac Dist is sent as pump around over bed-1 on flow control.
Rest goes to storage
Air Fin Cooler
Crude/ Vac Distillate
exchangers
Crude/ Vac Distillate
exchangers
RefluxReflux
PAPA
142 0C142 0C
60 0C60 0C
142 0C142 0C
60 0C60 0C
BED-1BED-1
BED-2BED-2
Vac DistVac Dist
LVGOLVGO
Drawn off from chimney tray below bed no 2 into LVGO Vessel
Vessel level is controlled by adjusting rundown flow
From vessel it is pumped through MP steam generator exchanger of CDU
Then to crude preheat exchangers
Finally cooled with tempered water and sent to storage / FCC feed
LVGO
Vessel
LVGO
Vessel
MP Steam GeneratorMP Steam Generator
Crude Crude
Tempered Water
Tempered Water
LVGO ProductLVGO Product
ReturnReturn
Return Return
BED-1BED-1
BED-2BED-2
238 0C238 0C
80 0C80 0C
HVGOHVGO
Drawn off from chimney tray below bed - 3
Vessel level is controlled by adjusting rundown flow
Pump discharge goes back as reflux
Remaining goes as pump around, FCC/Storage after cooling with crude / tempered water.
CrudeCrude
BED-2BED-2
BED-3BED-3
BED-4BED-4
Reflux Reflux
FCFC
CrudeCrude
Storag
e
Storag
e
Tempered Water Supply
Tempered Water Supply
FCCUFCCU
Return Return
HVGOHVGO
293 0C293 0C
230 0C230 0C
293 0C293 0C
170 0C170 0C
80 0C80 0C
HHVGOHHVGO
Draw off is from below Draw off is from below Bed-4 into HHVGO Bed-4 into HHVGO vessel.vessel.
Vessel level is cascaded Vessel level is cascaded with rundown flow control.with rundown flow control.
HHVGO is first cooled by HHVGO is first cooled by MP steam generation MP steam generation (CDU)(CDU)
Then split in twoThen split in two First part goes as quench to First part goes as quench to
HHVGO vessel. HHVGO vessel. Quench flow is regulated by Quench flow is regulated by
pump discharge pump discharge temperaturetemperature
Second Part goes for LP Second Part goes for LP steam generation (VDU), steam generation (VDU), then to FCCU / Storage.then to FCCU / Storage.
HVGOHVGO
BED-4BED-4
MP Steam GeneratorMP Steam Generator
TCTC
LP Steam GeneratorLP Steam Generator
StorageStorageFCCUFCCU
HHVGOHHVGO
FCFC
QuenchQuench
390 0C390 0C
230 0C230 0C
170 0C170 0C
VACUUM RESIDUEVACUUM RESIDUE
Vac Residue is the bottom product - first pumped through Crude preheat train to cool it down to 290 0C
Then Sent back to tower as
quench, to control cracking Cooled further against crude
to 190 0C
Vac residue finally leaves the unit as VBU Feed Storage VBU Blending
CrudeCrude
CrudeCrude
TCTC
FCFC
Superheated LP SteamSuperheated LP Steam
QuenchQuench
VBU FeedVBU Feed
Bitumen unit
Bitumen unit
StorageStorage
360 0C360 0C
290 0C290 0C
190 0C190 0C
•Introduce stripping steam before pulling vacuum so that sudden expansion is not there•While stripping steam is introduced, care should be taken so that column bottom level is not too high•Vacuum pulling / vacuum breaking should be done gradually
PRECAUTIONS & TROUBLE SHOOTINGPRECAUTIONS & TROUBLE SHOOTING
START UP SEQUENCE FOR START UP SEQUENCE FOR CDU/VDU CDU/VDU
•Flushing of all the Process and utility Systems•Chemical Cleaning of Compressor piping•Alkali boil out of the Steam generation drums•Leak test of all the Process and Utility Systems•Pump no load and Load trials•Commissioning of Utilities system inside the unit•Refractory dry out of the Furnaces•Vacuum hold test of the Vacuum column section•Removal of air from the system by Steaming out the unit•Backing-in fuel gas into all the systems•Draining water from the system•Preparation for cold oil circulation in CDU
START UP SEQUENCE START UP SEQUENCE
START UP SEQUENCE START UP SEQUENCE
•Charging crude for cold oil circulation in CDU•Preparation for crude heaters light up•Crude heaters burner light up:•Raising temperature for hot oil circulation•Stripping steam injection in crude column•Routing of atmospheric residue to VDU•Chemical injection in crude column overhead section
START UP SEQUENCE START UP SEQUENCE
•Establishing pump around and product circuit
(I )Heavy Naphtha Product Circuit(II) Light kerosene Product Circuit(III) Top Pump around Circuit(IV) Heavy Kerosene Pump around Circuit(V) Heavy Kerosene Product Circuit(VI) LGO Pump around Circuit(VII) LGO Product Circuit(VIII) HGO Pump around Circuit(IX) HGO Product Circuit
VDU START UP SEQUENCE VDU START UP SEQUENCE
•Preparation for cold oil circulation in VDU•Charge LDO for circulation in VDU bottom•LDO circulation in HHVGO system•Vacuum heaters light up and hot oil circulation•Replacement of LDO with RCO after raising temperature•Fill up of vacuum distillate and LVGO system with LGO and HGO from CDU•Introduction of stripping steam and vacuum pulling•Switch over of atmospheric residue to vacuum column•Rising of vacuum heater O/L temperature to 350 °c and injection of turbulizing steam in to heater coil•Vacuum furnace cot raising and product routing
SHUTDOWN SEQUENCE FOR SHUTDOWN SEQUENCE FOR CDU/VDU CDU/VDU
CDU/VDU SHUT DOWN SEQUENCE CDU/VDU SHUT DOWN SEQUENCE
•General•Through Put Reduction•Vacuum Furnace COT reduction and Vacuum product routing to off spec•Stripping steam cut off in Vacuum column•Vacuum breaking in Vacuum column•Velocity steam cut off and Vacuum column product thinning with Wash oil•CDU Off Gas compressor Shutdown•Crude Heater COT reduction and Routing Crude products to Off spec
CDU/VDU SHUT DOWN SEQUENCE CDU/VDU SHUT DOWN SEQUENCE
•Stripping steam cut off in Crude Column and Switching off of Chemical injections in Crude column overhead•Shutdown of Sat Gas Unit•Desalters Isolation and Switching off Chemical injections•Establishing hot oil circulation in bottom loop•Deinventoring
EMERGENCY SHUTDOWN EMERGENCY SHUTDOWN
EMERGENCY SHUTDOWNEMERGENCY SHUTDOWN•Loss Of Feed•Power Failure•Power Dip•Instrument Air Failure•Cooling Water Failure•Sea Cooling Water Failure•LP Steam Failure•MP Steam Failure•DCS Failure•Heater Tube Rupture•Crude Charge Pump Failure
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