Refinery Overview

8/13/2019 Refinery Overview

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Refinery

Overview


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We will seeCrude and its characteristics

Typical Refinery Configuration

Major refinery Process1.Distillation (CDU/VDU)

2.Alkylation3.Merox4.FCC ( For gas oils)5.Catalytic Cracking (Naphtha)

6.Hydro treating and Cracking7.Delayed Coking8.Sulphur Block unit (Sulphur, Sour water stripper, Amineregeneration units)

Questions ???


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3

ELEMENTAL COMPOSITION(%)RANGESELEMENTAL COMPOSITION(%)RANGES

FOR CRUDEFOR CRUDE

Carbon 83.9-86.8Carbon 83.9-86.8

Hydrogen 11.0-14.0Hydrogen 11.0-14.0

Sulphur 0.06-8.0Sulphur 0.06-8.0Nitrogen 0.02-1.7Nitrogen 0.02-1.7

Oxygen 0.08-1.8Oxygen 0.08-1.8

Metals 00-0.14Metals 00-0.14 Mainly vanadium and Nickel (Iron,Mainly vanadium and Nickel (Iron,magnesium ,Aluminum , Copper, Silver inmagnesium ,Aluminum , Copper, Silver in

traces)traces)


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4

PRINCIPAL TYPES OFPRINCIPAL TYPES OFHYDROCARBON PRESENTHYDROCARBON PRESENT

Composition of Crude oil

Paraffins:Straight chain compounds. Lighter ones are gas,heavier molecules are liquid (oil) and solid (wax).

Naphthenes:consist of carbon rings, with or without sidechains; saturated with hydrogen; Naphthenes are chemicallystable. Lighter Naphthenes are liquids but heavier ones couldbe solid.

Aromatics:compounds having a ring of 6 carbon atoms-Bzstructure they are relatively unstable.


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5

Paraffins


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6

Naphthenes


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7

Aromatics


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Classification of Crude oil Gravity as basis

API Gravity = 141.5 - 131.5

Sp. Gravity API Gravity is higher for lighter crude and lower for heavier crude.

Lighter Crude API>350

e.g, Mumbai High crude 400API

Medium Crude API between 250&340

e,g, Arabian crude: 340API

Heavy Crude API


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DIFFERENCE BETWEEN

PARAFFINC & NAPTHENIC BASE

9

Paraffinic NapthenicSP.gravity of crude Low High

Yield of gasoline High Low

Octane no.(St. run) Low HighSulphur content Low High

Smoke pt. Kerosene High Low

Cetane value HSD High LowPour point of HSD High Low


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Processing Schemes vs. type ofCrude oil

Refinery processing scheme and product

yields depend on type of crude in terms ofchemicals natureand gravity. Typically:

Paraffinic crudesare good for straight run fuel

production e.g diesel.

Light crudeyields more gasoline.

Medium crudegood for diesel production.

Heavy crudesgive better bitumen

Naphthenic crudegood for Lubricating oil.10


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11

Flow scheme of a modern refinery


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Reactions Resulting in CorrosionReactions Resulting in Corrosion

MgClMgCl22+ H+ H22O Mg(OH)O Mg(OH)22 +2HCL+2HCL

MgClMgCl22+ H+ H22S MgS +2HClS MgS +2HCl

Fe + 2HCl FeClFe + 2HCl FeCl22 +H+H22

FeClFeCl22 + H + H22S FeS + 2HClS FeS + 2HCl

Fe + HFe + H22S FeS + HS FeS + H22

HCl attacks heater tubes, trays, lining, OVHDHCl attacks heater tubes, trays, lining, OVHD

condensercondenser Corrosion controlled by neutralizing amineCorrosion controlled by neutralizing amine

injection and filming amines as inhibitorsinjection and filming amines as inhibitors


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DESALTER

CRUDE AT 120 - 140 DEG C

PROCESS WATER

LDT

LDCV

TRANSFORMER

100-120 DEG C

PDI

DESALTED CRUD


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WaterWaterCrude EmulsionCrude Emulsion


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Distillation of Crude OilDistillation of Crude OilDistillation of Crude OilDistillation of Crude Oil


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Atmospheric Distillation

Column Typical 40 to 50 actual trays No. of trays from bottom

4 to 6 bottom stripping4 to 6 flash zone/heavy gas oil

4 to 6 heavy gas oil/light gas oil

4 to 6 light gasoil/kerosene4 to 8 kerosene/heavy naphtha

4 to 8 heavy naphtha/light naphtha

2 to 3 pump arounds each Top temperature: 80 to 100 above water dew point (1200to

1300C typical)

Flash zone below cracking temperature: 3850

C typical


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Crude Distillation

Pump around Typically at product draw tray

return 2 to 3 trays above

60 to 800c temperature drop Stripping steam

Bottom: 18 to 24 kg /std m3 of RCO

Side strippers: 12 to 18 kg /std m3 ofstripped product


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Typical Op. Condns. of Crude Column

Crude Type 30 deg. API 40 deg. API

Op. Parameters

REF. DRUM

Pr., Kg/cm2(a) 3.0 3.1

temp., deg. C 45 45

COL. TOP

Pr., Kg/cm2(a) 3.5 3.6temp., deg. C 103 114

FL. ZONE Pr., Kg/cm2(a) 3.9 4.0

temp., deg. C 384 362O/F % 4 to 6 4 to 6

COT temp., deg. C 387 364.5


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Vacuum DistillationVacuum DistillationVacuum DistillationVacuum Distillation DRY DAMP WET

Top pressure mmHg a 8 25 75

Flash zone pressure mmHg a 24 42 95

Heater outlet temp.0C 395 405 420

Column dia Highest Int Least

Steam Nil Int Highest

Economics normally in favor of damp vacuum


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COLUMN INTERNALS


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22

Crude Distillation Column


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23

Vacuum Distillation Column


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24

Alkylation Alkylation combines low-molecular-weight olefins (primarily a mixture of

propylene and butylene) with isobutene in the presence of a catalyst, eithersulfuric acid or hydrofluoric acid.

The product is called alkylate and is composed of a mixture of high-octane,branched-chain paraffinic hydrocarbons.

Alkylate is a premium blending stock because it has exceptional antiknock

properties and is clean burning. The octane number of the alkylate dependsmainly upon the kind of olefins used and upon operating conditions.


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ChemistryRSH + NaOH NaSR + H2O (1)

4NaSR + O2+ 2 H2O 4NaOH + 2RSSR (2)

4RSH + O2 2RSSR + 2 H2O (3)

Reaction (1) is reverssible and favourable in forwarddirections, For

Low molecular weight mercaptans. Low temperature.

High Caustic concentration.


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operating conditions

EquipmentsEquipments TemperatureTemperature

( (00C)C)

PressurePressure

(Kg/cm(Kg/cm22g)g)

Caustic prewashCaustic prewashcolumncolumn

4545 19.519.5

11stststage CFC causticstage CFC caustic

wash contactorwash contactor4545 1818

22ndndstage CFC causticstage CFC causticwash contactorwash contactor

4848 17.517.5

Oxidizer TowerOxidizer Tower 5252 3.5-5.53.5-5.5

CFC solvent washCFC solvent wash

contactorcontactor5252 33


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CATALYTIC REFORMING

CATALYTIC REFORMING IS AN IMPORTANT PROCESS INPETROLEUM REFINING AND PETROCHEMICALS INDUSTRIES.

VALUE ADDITION TO STRAIGHT RUN NAPHTHA AND HASSIGNIFICANT INFLUENCE ON OVERALL ECONOMICS OF THEINDUSTRY

CATALYTIC REFORMING PROCESS BASICALLY CONVERTSPARAFFINS AND NAPHTHENES TO HIGH OCTANE AROMATICCOMPONENTS AND THEREBY PRODUCES

HIGH OCTANE MOTOR GASOLINE BLENDING STOCK RICH CONCENTRATES OF AROMATICS VIZ. BENZENE, TOLUENE

AND XYLENES (BTX) H2 REQUIRED IN REFINERY FOR HYDROTREATING /

HYDROCRACKING, THUS MAKING MORE ECONOMIC VIABLEPROCESS LPG AN ANOTHER VALUE ADDED PRODUCT.


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SCHEMATIC OF THE CCR PLATFORMING PROCESS


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DEHYDROCYCLISATION OF PARAFFINS

CH3 CH2 CH2 CH3 CH2 CH2 CH2 CH3

CH2 CH2 CH2CH2 CH2 CH2

H2C

H2C

H2C CH2

CH2

CH2

3H2 +

TOLUENEMETHYL CYCLEOHEXANE

(O.N. = 120)

C7H16(O.N. = 0)C7H14

CYCLI-

SATION

DEHYDRO-

GENATION

3

2

1

+ H2


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Fluid Catalytic Cracking Oil is cracked in the presence of a finely divided catalyst, which is maintained in an

aerated or fluidized state by the oil vapours.

The fluid cracker consists of a catalyst section and a fractionating section that operatetogether as an integrated processing unit.

The catalyst section contains the reactor and regenerator, which, with the standpipe andriser, form the catalyst circulation unit. The fluid catalyst is continuously circulatedbetween the reactor and the regenerator using air, oil vapors, and steam as theconveying media.

Preheated feed is mixed with hot, regenerated catalyst in the riser and combined with a

recycle stream, vapourized, and raised to reactor temperature (485-540C) by the hotcatalyst.

As the mixture travels up the riser, the charge is cracked at 0.7-2 bar.

In modern FCC units, all cracking takes place in the riser and the "reactor" merelyserves as a holding vessel for the cyclones. Cracked product is then charged to afractionating column where it is separated into fractions, and some of the heavy oil is

recycled to the riser.


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The basic process of catalytic crackingThe basic process of catalytic crackingThe basic process of catalytic crackingThe basic process of catalytic crackingThe basic process of catalytic crackingThe basic process of catalytic crackingThe basic process of catalytic crackingThe basic process of catalytic cracking

Hydrocarbon feed is brought into intimate contact with hot

catalyst The feed is vaporized and cracked and leaves behind

coke The vapors and catalyst are separated

The vapors flow into a separation section The coke-laden catalyst is brought into contact with air The coke burns and leaves behind hot regenerated

catalyst The hot catalyst is brought into intimate contact with

hydrocarbon feed and the cycle continues..


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Fluid Catalytic Cracking


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Process flow diagram - HCU

VV-2VV-1

VV-4

VV-3

VV-6

VV-5

CC-01

VV10

CC-05

VGO/CGO

M/U H2

RB-01

RB-02

FF-01

FF-02

RECYCLE H2

RB-03

RGCHHPS.

CLPS off gas

To H2 UNIT

HY. [email protected]/H

SKO

71.131T/H

HSD

48.894T/H

LPG

3.874T/H

LT. NAPH.

@14.57T/H

KA002A

154

M3/Hr

3600C/170 Kg/Cm2

3870C/170Kg/cm2R.H2

2nd STAGE

141 m3/Hr

KA003A/B/C CC-06

FF-3

157 kg/cm21.1kg/cm2

GN001

35 kg/cm2

2200C

PRT

568KW

VV13

Gas 1.482 T/H

CHPS

HHPS

HLPS

CLPS

380

4130C

4100C


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Desulfurization

R

R CH SH + H2 R CH2 R + H2S

Denitrification

RCH2CH2CH2NH2+ H2 RCH2CH2CH3+ NH3

In the reactors, sulfur and nitrogen are removed from the

feedstock. In general, the carbon skeleton of the feed molecule isnot altered by heteroatom removal; however, the boiling point ofthe molecule decreases by 27-54 C for sulfur compounds and upto 104C for nitrogen compounds.

Olefin saturation

RCH2CH=CH2+ H2 RCH2CH2CH3

Hydrocracking

RCH2CH2CH2CH3 + H2 RCH3 + CH3CH2CH3

Process Chemistry

H d d t lli ti (HDM)


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Fig. 5 Reaction mechanism for

Hydrodemetallization (HDM)

H d d lf i ti (HDS)


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Fig. 6 Postulated mechanism for Hydrodesulfurization

Hydrodesulfurization (HDS)


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Fig. 7 Typical Desulfurization reactions

Hydrodenitrification (HDN)


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Hydrodenitrification (HDN)

Fig. 8 Postulated mechanism for Hydrodenitrification


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T i l H t t


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Types of sulphur compounds

Mercaptans R-SH

Aliphatic Sulfide R-S-R

Disulphide R-S-S-R

Thiophenes

Benzo-thiophene

Typical Heteroatoms

S

C C

CC

S

C

C

S

C

C


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Nitrogen compounds

PyrroleHN

Indoles

NH

Carbazoles

NH


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Pyridine, quinolines

& acridines

Oxygen compounds Furan,

Carboxylic acids & phenols

Aromatics Benzene,

Tetralin & biphenyl

Naphthalenes and

anthracenes

N NN

OH

H2 Consumption & Heat Release


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Reaction Hydrogen Consumption BTU/SCF

Desulphurization 3 mol H2per mol of Sulfur 60

Denitrification 5 mol H2per mol of Nitrogen 65-75

Olefin Saturation 1 mol H2per mol of C=C 130-160Aromatic Saturation 3 mol H2per mol of ring Saturated. 70-85

Heat Release Thumb Rule : 130 BTU/SCF for Olefin Saturation.

60 BTU/SCF for every thing else.

Typical Classes Of Molecule in HydroprocessingParaffins Poor Pour,Cloud, Octane ; Good Cetane

Iso-paraffins Good Octane

Olefins (mono) Good Octane (comes from FCC & Coker).

Olefins (di) Foul Hydroprocessing equipment and catalyst.

Naphthenes Poor Octane, Acceptable CetaneAromatic (mono) Good Octane (Large amount in FCC Product)

Aromatic (di) Good Octane, Poor Cetane.

Aromatic (poly) Foul Hydroprocessing Catalyst

H2Consumption & Heat Release

Order Of Reaction


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Demetalization

(Metals Removal From Feed) EASY

Olefin Saturation

(Destroy Double Bond With H2)

Desulfurization

(Sulfur Removal From Feed)

S + H2H2S

Denitrification

(Nitrogen Removal From Feed)

N + H2NH3

Aromatics Saturation

Cracking

(Lower Boiling Point

C12 C8 + C4 H2 HARD

Order Of Reaction

DCU FLOW DIAGRAM


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VV-01

RFO

# 35

# 27

KERO-I

-KERO-II

183oC

251oC

CC-03

CC-04

GO

HGO

293oC

341oC

#25

# 20

GO CR

HGO CR

CC-01

FF-01

RB-01 RB-02

CC-02

445oC, 2.5 kg/cm2

EA-06

SOUR WATER

OFF GAS

425oC

P-1.75Kg/cm2

T-115oC

320oC

Cold VR

Hot VR

Slop

PREHEAT

502 oC

BFW

VV-02

DCU FLOW DIAGRAM

# 37

# 43

#29

STEAM GEN

SS

SWITCHVALVE


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OPERATING CONDITIONS

HEATER OUTLET TEMPERATURE, oC 480 510

COKE DRUM TEMPERATURE, oC 440 465

COKE DRUM PRESSURE, Kg/cm2 1 5

RECYCLE RATIO, VOL/VOL%OF FEED10 100

CYCLE TIME 24 hrs

INTRODUCTION T VISBREAKING


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INTRODUCTION To VISBREAKING

The atmospheric or vacuum residual oils are veryviscous and have high pour points. It is difficult topump them as fuel oil. Therefore, they must beblended with relatively high value distillates to meet

the finished product viscosity specification.

Visbreaking, a thermal conversion process has beenfound to be a good process which reduces the

viscosity and pour point of processed residues. Tomeet the fuel oil specifications, a small quantity ofdiluents or cutter stock (Light Gas Oil) may berequired.

Visbreaking also produces a small amount of lightgases and gasoline.

VISBREAKING


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A mild liquid phase thermal conversion process to reduceviscosity and pour point of residues (coke formation avoided) forproducing lower viscosity product suitable to use as stable fuel oil.

Products include:

VISBROKEN GASES (UP TO C4-)

VISBROKEN NAPHTHA (UP TO 150oC)

VISBROKEN FUEL OIL (150oC+)

OPTIONS FOR REFINERS

Production of visbroken gas oil to be used as diesel

Production of visbroken vacuum gas oil to be used as feed stock

for FCC operation

Production of visbroken vacuum residues to be used as refineryfuel oil

TYPICAL COMBINATION CRACKING UNIT


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Feed

Visbreaker Heater

Recycle Heater

Main Fractionator

Gas

Gasoline

Gas Oil

Vacuum

Vac.Fractionator

Residue

Operating conditions:


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Operating conditions:

Visbreaking temp. - at the heating coil outletrange from 450 - 500 C, depending on thedesign of the unit and the nature of the feed

stock.

Pressure - may vary between 4 and 20 bars,but higher pressure is often preferred, sincethis gives greater control over residence timeby minimizing vaporization.

Residence Time Temperature andresidence are interchangeable within certainlimits


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AN OVERVIEW OF SRB

ATU

ARU SWSSRU

SRB

H2S RICH GAS

NH3 RICH GAS


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SWS

GSU ARU

SRU

inciS.W.EXDCU

S.W.ex HCU

SOUR FUEL

GAS Ex DCU

SOUR

FUEL GAS

Ex HCU

SWEET FUEL GAS

(


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Claus ProcessClaus Process

H2S O2

Catalytic ConverterCatalytic Converter

Sulphur Condenser

Further Treatment

LP Steam

Sliquid

200 - 3500

C(340 - 6600F)

130 - 2000C

(270 - 3900F)

S Yields in the range of 80 90%

3 H2S + 3/2 O2 3/x Sx + 3H2O

Modified-Claus ProcessModified-Claus Process


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Modified-Claus ProcessModified-Claus Process

Reaction Furnace

Wasteheat exchanger

Catalytic converter

Sulphur condenser

Further treatment

H2S

HP steam

LP steam

S liquid

925-12500C

(1700-23000F)

170-3500C

(340-6600F)

130-2000C

(270-3900F)

O2


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CLAUS PROCESSCLAUS PROCESSCLAUS PROCESSCLAUS PROCESS THE CONVENTIONAL CLAUS PROCESS WAS

DELOVEPED C. F. CLAUS. THE PROCESS WAS LATER

MODIFIED BY I. E. FRABENTHE PRESENT PROCESS CONSISTS OF A THERMAL

STAGE FOLLOWED BY TWO OR THREE CATALYTIC

RECTOR STAGES. THE THERMAL STAGE CONSISTS OF

REACTION FURNACE, WASTE HEAT BOILER AND

CONDENSER. IN THIS STAGE, H2S IS OXIDISED BY

COMBUSTION AIR TO SO2 ACCORDING TO THE

REACTION.3H2S +3/2O2 2H2S + SO2+H2O


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EACH CATALYTIC STAGE CONSISTS OF FEED HEATER, CATALYIST BEDEACH CATALYTIC STAGE CONSISTS OF FEED HEATER, CATALYIST BEDEACH CATALYTIC STAGE CONSISTS OF FEED HEATER, CATALYIST BEDEACH CATALYTIC STAGE CONSISTS OF FEED HEATER, CATALYIST BED

AND SULPHUR CONDENSER. CHEMICAL THERMODYNAMICAND SULPHUR CONDENSER. CHEMICAL THERMODYNAMICAND SULPHUR CONDENSER. CHEMICAL THERMODYNAMICAND SULPHUR CONDENSER. CHEMICAL THERMODYNAMIC

EQUILIBRIUM IS ESTABLISHED IN EACH BED ACCORDING TO THEEQUILIBRIUM IS ESTABLISHED IN EACH BED ACCORDING TO THEEQUILIBRIUM IS ESTABLISHED IN EACH BED ACCORDING TO THEEQUILIBRIUM IS ESTABLISHED IN EACH BED ACCORDING TO THE

CLAUS REACTIONCLAUS REACTIONCLAUS REACTIONCLAUS REACTION

2H2H2H2H2222S + SOS + SOS + SOS + SO2222 3/n Sn + 2H 3/n Sn + 2H 3/n Sn + 2H 3/n Sn + 2H2222OOOO

FOR MAXIMUM SULPHUR RECOVERY, IT IS IMPORTANT TO MAINTAINFOR MAXIMUM SULPHUR RECOVERY, IT IS IMPORTANT TO MAINTAINFOR MAXIMUM SULPHUR RECOVERY, IT IS IMPORTANT TO MAINTAINFOR MAXIMUM SULPHUR RECOVERY, IT IS IMPORTANT TO MAINTAINHHHH2222S : SOS : SOS : SOS : SO2222 MOLE RATIO OF 2:1. DEPENDING UPON THE HMOLE RATIO OF 2:1. DEPENDING UPON THE HMOLE RATIO OF 2:1. DEPENDING UPON THE HMOLE RATIO OF 2:1. DEPENDING UPON THE H2222SSSS

CONCENTRATION IN THE FEED.CONCENTRATION IN THE FEED.CONCENTRATION IN THE FEED.CONCENTRATION IN THE FEED.


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REACTION FURNACEREACTION FURNACEREACTION FURNACEREACTION FURNACE

MAIN REACTIONS

H2S + SO2 S + H2O

2H2S + SO2 2H20 + 3S

2NH3+ O2 3H2O + N2

SIDE REACTIONS

CH4+ 2O2 CO2+ 2H2O

CO2+ H2S COS + H2OCOS + H2S CS2 + H2O

2H2S + HEAT 2H2 + S2


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SOUR WATER STRIPPER


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S

T

R

I

P

P

E

R

I

S

T

R

I

P

P

E

R

II

S.W.

TANK

S / D

CBD

WPC

1001

WLC

1004

SDV

1007

SDV

1004

WPC1101

WPC

1102

WTC

1107 WFC

1105

WFF

C

1102

WTC

1103

WLC

1106

WPC1201

WTC

1205WFC

1202

WFFC

1201

WLC

1201

S.W.ex DCU SW

S.W. ex HCU SW

S.W, ex GSU

F M

COOLER

EE-

001

N2

EE

03A/B

WFC

1101

EE

002PA

001

STD.W.

COOLER

EA-02

EA-01

EE-04

EE-05

SL

SM

WLC

1102

WF

C

1002

PA

003

PA

02

PA-04

WFC1203

TO

EE01

PA

005

FLAR

E

INCI

.

FLARE

SRU-VV02

SRU-VV02

TO DCU/ETP

H2S RICH GAS

C

W

SOUR WATER STRIPPER

SOUR WATERSOUR WATERSOUR WATERSOUR WATER


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NITRGEN AND SULPHUR COMPOUNDSIN CRUDE OILS

H2S + NH3

NH3

WATER CONTAININGNH3WITH SMALL AMOUNTS OF H2S

SOUR WATERCOMPOSITION NH3 100 5000ppmw H2S 100 10000ppmw

CH, PHENOL, HCS, CO2, COOH, S-, M+

ADVERSELY AFFECTS BOILOGICAL LIFE.TREATED BEFORE DISCHARGING

REFINING PROCESSES

AMINE TREATING (-H2S)

WATER WASH

How much do we use?


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63

How much do we use?

Imagine a lake 10 miles long, 9 miles wideand 60 feet deep. Fill that lake with oil. Thatwould be about as much oil as the entireworld uses in one year. The United Stateswould use about 1/4 of it.


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THANK YOUTHANK YOU

IOCL MATHURA REFINERY


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C

D

U

V

D

U

VBU

BBU

FCCU

OHCUDHDT

DHDS

N

S

L

H2 Plant

CRUMSQP

LPG

NAP

HVY

NAPH

ATF

KERO

AGO

NAPH

DIESEL

NAPH

DIESEL

LIQ

FUEL

VGO

VR

VR

VB TAR

VB NAPHTHA

BITUMEN

ST RUN NAPH

REFORM

F

CC

LTGASO

MS

FCC TCO

AR

LPG

LHT NAPH

HVY NAPH

KERO

DIESEL

RELIANCE JAMNAGAR REFINERY COMPLEX


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CDU

VD

U

KeroMEROX

Sat GasConcn

Delayed

Coker

VGO

HDT

DHDT

FCCU

HEAVYNAPHHDT

Gasoline

MEROX

CRUDE

Light

Kerosene

ATMResidue

Diesel

HAGO

Diesel

Unstabilis

ed

Naphtha

Naphtha

Coke to PPVacuum

Resid

LIGHTNAPH

HDT

H2 PLANT

H2

C5 -C6

Unsat gasconc.

LPGMEROX

PropyleneRecovery

LPG

Heavy kerosene

C5

-C10

NC

6/BN

Sat LPG

MEROXC3/C4

LPG

NormalButane

Recovery

N- Butane

Ga

soline

toStorage


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Source K J Pai, L &T


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3-D Model View


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Fig.

Construction status - RefineryConstruction status - RefineryConstruction status - RefineryConstruction status - Refinery

Fi


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HCU / DHT Overall Progress:92.8%

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Fig.4

Overview of Reliability Concerns for Hydroprocessing PlantsOverview of Reliability Concerns for Hydroprocessing PlantsOverview of Reliability Concerns for Hydroprocessing PlantsOverview of Reliability Concerns for Hydroprocessing Plants


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Richmond Isomax Fire 1989Richmond Isomax Fire 1989Richmond Isomax Fire 1989Richmond Isomax Fire 1989


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Brittle FractureBrittle FractureBrittle FractureBrittle Fracture


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Brittle FractureBrittle FractureBrittle FractureBrittle Fracture


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Richmond steam generator brittle fracture duringhydrotest

TANKAGE AREA


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Essar Oil Refinery, Vadinar


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Reaction sectionReaction sectionReaction sectionReaction section

Riser (reactor)

Maintains the feed and the catalyst in close contact as

a well-dispersed mixture while avoiding backmixing

Designed to minimise catalyst sticking to the walls


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Reaction sectionReaction sectionReaction sectionReaction section

Riser Termination Device

Designed to eliminate post-riser cracking thermal / secondary

Stripping zone

Designed to keep hydrocarbons out of the

regenerator

Reactor internalsReactor internalsReactor internalsReactor internals


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Riser Termination device

Catalyst to regen

Vapors to fractionator

Secondary cyclones

Stripper baffles

Refinery Overview

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