INTRODUCTION
The world demands in hydrocarbons grow this because of the consumption and the massive
production of goods and services, this is why in order to satisfy the demand of the national and
international market many companies have embarked on the exploration, the production , and crude
oil refining.
Our report will focus on the refining of crude oil through the national refining company of Cameroon
“SONARA”.
Indeed SONARA is a crude oil refining company and to meet the challenges related to refining it has
units that allow it to carry out its objectives, as follows the units used at SONARA.
The atmospheric distillation unit (U10), overhead gasoline hydrotreating unit (U20), the gasoline
stabilization and fractionation unit (U30), the liquefied petroleum gas processing unit (U40), the
catalytic reforming unit (U50), the kerosene desulfurization unit (U60) and finally the process water
treatment unit (U70).
We will try throughout our report to shed light on how the 10, 20, 30 and 40 units work.
SUMMARY
INTRODUCTION 1
CONTENTS 2
I. ATMOSPHERIC DISTILLATION (Unit 10) 3
1. ROLE 3
2. UNIT LOAD CIRCUIT 10 3
3. FIRST PREHEATING TRAIN 4
4. DESALTER 4
4.1. ROLE 4
4.2. OPERATING PRINCIPLE 5
5. THE OVEN (10F1) 9
5.1. ROLE 9
5.2. OPERATING PRINCIPLE 9
6. THE ATMOSPHERIC DISTILLATION COLUMN (10C1) 10
6.1. ROLE AND DESCRIPTION OF COLUMN 10
6.2. CIRCULATING REFLUXES 12
6.3. PRODUCT WITHDRAWN FROM ATMOSPHERIC DISTILLATION COLUMN 13
II. HEAD ESSENCES HYDROTREATMENT UNIT (UNIT 20) 18
1. ROLE 18
2. OPERATING PRINCIPLE 18
III. STABILIZING AND FRACTIONATING ESSENCES (UNIT 30) 22
1. ROLE 22
2. OPERATING PRINCIPLE 22
IV. LIQUEFIED GAS FRACTIONATION UNIT (UNIT 40) 25
1. ROLE 25
2. OPERATING PRINCIPLE 25
V. EQUIPMENT AND CHARACTERISTICS 28
1. Balloons 28
2. Columns 28
3. Ovens 29
4. Reactors 29
5. Compressor 29
6. Aero 30
7. Push-ups 32
8. Exchangers 37
I. ATMOSPHERIC DISTILLATION (Unit 10)
1. ROLE
The role of atmospheric distillation is the separation of the different fractions contained in the crude
oil according to their volatilities at given temperatures and pressures.
2. UNIT LOAD CIRCUIT 10
The crude oil after unloading (reception) must be stored for at least 48 hours to allow a good water /
hydrocarbon separation in the crude tanks, a purge is then carried out. In order to have a fairly good
quality crude, this before arriving at the 10P1A/B charge pumps passes through 10FL1A/B filters
which are intended to retain sediments (solid impurities) as well as suspended matter . The charge
coming from the crude tanks (A10, A11, A12, A13) before passing through the charge pumps 10
P1A/B receives an injection of demulsifier (10 P17X), heavy slops (10 P14) and recirculation (10
XV505). The pumps suck in the product at about 0.5 bars (because it all depends on the height of the
product in the tank) and pushes it back at about 20 bars.
The charging circuit of unit 10 before entering furnace 10F1 goes through three essential stages:
• The first preheat train, 10E1, 10E2, 10E3, 10E32, 10E4B/A
• The desalter, 10B1
• The second preheating train, 10 E5B/A, 10E6, 10E7, 10E9A,
10E31, 10E35C/B/A, 10E30, E9C/B
3. FIRST PREHEATING TRAIN
Indeed the first preheating train, allows the conditioning of the crude for desalting, and participates
in the intimate mixing between the demineralized water and the crude, before entering the first
preheating train, there is an injection of water from desalting (about 131oC) this contributes to the
dissolution of some of the salts contained in the crude.
And note that the crude enters the first exchanger 10 E1 on the shell side, it then enters the other
exchangers on the bundle side, after gaining calories, this mixture is injected into the desalter at a
temperature of approximately 130-145oC at a pressure of 12 bar. Note that there is a hot water/raw
mixture before exchanger 10 E1 inlet favored by a mixing valve 10PDV0099 and cold desalter water
inlet "Not used"
Diagram of the first preheating train
4. THE DESALTER
4.1. ROLE
Crude oil also contains hydrocarbons, impurities which are in the form of sulphurous, oxygenated,
nitrogenous, metallic compounds and especially salts.
The role of the desalter is to rid the crude of mineral salts which can cause considerable damage in
the units.
4.2. OPERATING PRINCIPLE
. The main objective of the desalter is to eliminate the salts contained in the crude, among which we
can mention MgCl2, KCl, NaCl, CaCl2 which are present in the crude so as to limit the phenomena of
corrosion, fouling and clogging. lines, deteriorationns of the tubes.
Desalting is carried out in a tank with a capacity of 142m3, an average inlet flow of 320 m3 /h and an
outlet of 320 m3 /h (according to the setpoint given) and operating at a pressure of 12 bars and at a
temperature around 130 -145 0C, and involves four stages:
1. Injection of demineralised water and the water/raw mixture
2. Preheating the water/raw mixture
3. The electro coalescence of water droplets in a magnetic field
4. Settling
At the outlet of the desalter, the hydrochloric acid produced by hydrolysis of the salts contained in
the crude is neutralized by injection of soda (NaOH), flow rate... in order to perfect the properties of
the crude. Poor desalting has direct consequences on the operation of the atmospheric distillation
tower (corrosion at the top of the column)
Intervening reactions:
MgCl2 + H20 Mg(OH)2 + HCl
CaCl2 + H2O Ca(OH)2 + HCl
HCl + NaOH NaCl + H2O
After desalting, the crude is sent to the second preheating train thanks to the recovery pumps 10
P2A/B which deliver the desalted crude at a pressure of approximately 33 bars to the second
preheating train.
The second preheating train facilitates the work of the 10F1 so that it provides less energy (to save
the crude the maximum number of calories) recorded using the TJI34 thermocouple. In the second
preheating train there is a series of exchangers and its particularity is that it is at certain places
divided in two to allow the crude to gain calories more quickly:
Circuit of the second preheating trains
The crude is then divided into four passes to optimize the heating and there are four load flow
control valves: 10FV1, 10FV2, 10FV3 and 10FV4, then sent to the temperature of approximately 270
oC with a pressure of 14.8 bars in the 10F1 oven.
Table summarizing the inlet and outlet temperatures of the raw material in the two preheating trains
(Pulpiler)
Equipment Names Inlet Temperatures Outlet Temperature
Exchanger 10 E1 440C 66 0C
Exchanger 10 E2 66 0C 84 0C
Exchanger 10 E3 84 0C 84 0C
Exchanger 10 E32 0C HS 0C HS
Exchanger 10 E4A 0C 90 0C
Exchanger 10 E4B 90 0C 122 0C
Exchanger 10 E5A/B 121 0C 133 0C
Exchanger 10 E6 133 0C 165 0C
Exchanger 10 E7 165 0C 120 0C
Exchanger 10 E9A 120 0C 170 0C
Exchanger 10 E31 170 0C 175 0C
Exchanger 10 E35C/B/A 175 0C 220 0C
Exchanger 10 E9C/B 220 0C 242 0C
Crude pretreatment circuit (first and second preheating train and desalter) (U10)
5. THE OVEN (10F1)
5.1. ROLE
The role of 10 F1 is to provide the preheated crude with the additional calories necessary for its
partial vaporization in order to ensure better separation in the atmospheric distillation column, when
it reaches around 270˚C it obtains its transfer temperature at around 390˚ C (TI 52) to allow good
separation by volatility difference in column 10C1, check with temperature transmitters TT51
(regulation) and TT52 (safety).
5.2. OPERATING PRINCIPLE
Description of the 10 F1:
The 10 F1 is a cabin oven made up of horizontal tubes. The 10F1 oven consists of the following main
parts:
A radiation zone, essentially consisting of a combustion chamber, in which tubes are arranged
horizontally and connected to each other by welded elbows. The radiation consists of 48 tubes in 4
passes, sight glasses allowing the appearance of the flames and tubes to be observed, thermocouples
which indicate the temperature of the tube skins in order to avoid reaching their limit of mechanical
resistance.
The vault, we find there:
• explosion doors which open to decompress the combustion chamber of the furnace in the event of
a rise in pressure,
• a pressure sensor for measuring the depression, because the vault is the place most sensitive to
pressure variations.
A convection zone to recover the sensible heat of the fumes. We find there:
• the four passes of the crude in serpentines with tubes equipped with pins to increase the exchange
surfaces,
• A stripping steam superheater,
• 20 chimney sweeps which allow the soot to be blown off the pins in order to maximize heat
transfer,
• smothering steam injection line taps,
• thermocouples which measure the temperature of the tube skins,
• a pressure sensor for measuring the depression in the area.
The sole, we find there:
• 24 PILLAZD type Mixed Burners supplied by the fuel circuits. fuel oil (FO) and fuel gas (FG).
• 01 Acid gas burner from the process water treatment unit (Unit 70) HS.
• 05 Injections of the smothering steam circuit also used for sweeping the furnace.
The charge previously introduced into the furnace leaves the furnace at a temperature of 388-390oC
and goes into column 10C1 which is multiple withdrawal.
6. THE ATMOSPHERIC DISTILLATION COLUMN (10C1)
6.1. ROLE AND DESCRIPTION OF THE COLUMN
The role of the atmospheric distillation column is to separate the hydrocarbon molecules according
to their boiling point at a given pressure (2.2 to 3 bar)
The 10C1 has three parts:
• the expansion zone, or flash zone
• the grinding area
• the exhaustion zone.
The expansion zone is where the semi-vaporized crude enters the column.
The sudden decrease in pressure (15bar a - 2.2) creates a relaxation of fluid and produces a flash. The
vapors from the flash rise towards the rectification zone and the liquid descends towards the
exhaustion zone. The expansion zone is also the place where the releases of certain liquid valves of
unit 10 are returned (we can mention at the level of the desalter the 10PSV10, 10PSV11, 10PSV16,
10PSV17, at the level of the second preheating train 10PSV24, 10PSV21, at the level of the valves we
have 10B4A, 10B4B, 10B3, 10FL30A, 10FL30B). When no valve spits, barrier steam is sent into the
column to prevent the product from coming out of the column via this line: this is barrier steam
(saturated steam VS 380 oC and 4.5 bars).
In the rectification zone, all the liquid vapor traffic of the column takes place. The rectification area
starts from the flash area to the top of the column.
It has three (03) packing beds in the lower part and thirty-three (33) trays numbered from twentytwo (22) to fifty-four (54) in the upper zone. Each packing bed is equipped with a trough distributor
which distributes the liquid above the packing. The trays are valved and are equipped with inspection
hatches open during stops for column inspection.
The burnout zone is the area between the flash zone and the bottom of the column. It has six (06)
clamshell trays numbered from 1 to 6 from the bottom. These plates ensure contact between the
internal reflux and the flow of vapors generated by the stripping of the residue. The liquid (residue)
runs out to the bottom of the column below the trays. It is then withdrawn from the column under
control of level 10LIC1.
In addition, in order to protect the column against overpressure, it is equipped with three
interchangeable valves with exhaust to atmosphere 10PSV5, 10PSV6, 10PSV7 calibrated at 3.35 bars
to protect the column which under normal conditions operates at 2.5 bars.
In addition we have an injection:
ammonia to neutralize the acids contained in the column head vapors (HCl + NH3 NH4Cl)
and philm-plus (at the column head and RCS inlet, 54th trays) to prevent corrosion at the column
head
It should be noted that the circulating refluxes are very important in the liquid vapor contact in the
distillation column because it participates in the separation of the products of the various petroleum
cuts.
6.2. CIRCULATING REFLUXES
The circulating refluxes consist of a portion of liquid which is withdrawn from the column, cooled
outside and reinjected a few plates higher up the column. They therefore act as heat extractors from
the column, because they make it possible to extract the calories from the column in such a way as to
establish a decreasing temperature gradient necessary for the fractionation and to recover this heat
at interesting thermal levels. The reflux heating zone circulating in the column, which is heavily
loaded with liquid, can be considered as a real heat exchanger.
There is thus a quantity of heat taken from the column which depends on the circulating reflux flow
rate and the temperature difference between the outlet and the return to the column. The ΔT is
generally between 30°C and 90°C. the 10 C1 has three refluxes:
- The upper circulating reflux (RCS) column outlet 1600C column inlet 980C
- The average circulating reflux (RCM) column outlet 220 0C column inlet 145 0C
- The lower circulating reflux (RCI) column outlet 3360C column inlet 290 0C
The 10C1 is a vertical capacity, multiple withdrawal column, which separates hydrocarbon molecules
from crude oil into several intermediate and finished products:
• Head gasoline (petrol + gas), approximate withdrawal temperature 1350C
• kerosene, approximate withdrawal temperature 222 0C
• light diesel, approximate withdrawal temperature 286 0C
• heavy diesel, approximate withdrawal temperature 340 0C
• distillate, approximate racking temperature 375- 382 0C
• residue, approximate racking temperature 360 0C
6.3. PRODUCT WITHDRAWN INTO THE ATMOSPHERIC DISTILLATION COLUMN
The gasoline leaves at the head of the column mixed with the gas and passes through the air
condensers 10 A1 A/B/C/D/E/F/G/H is sent to the 10B2 reflux drum which operates at a pressure of
approximately 2.1 bar and a temperature of 45 oC. (Knowing that the product the bottom of the
10B2 is the load ofunit 20).
The kerosene is withdrawn from column 10C1 is sent to column 10C 2 where it undergoes reboiling
thanks to the lower circulating reflux which transfers the calories to the kerosene and passes to the
bundle side of exchanger 10E34 then goes to exchanger 10 E2 then into air cooler 10A3 and is finally
sent to unit 60 for desulfurization.
Descriptive diagram of the kerosene route from 10C2 to the stock
The light diesel is withdrawn from the column 10C1 is sent to the stripping column 10C3 and stripped
using saturated steam (VS 3800C and approximately 4bar) then sucked by the pumps 10 P7A/B it
passes through the exchangers 10 E6 and 10 E3 where it yields the calories to the crude and passes
through the air cooler 10A4 and goes into the tank 10 B3 is mixed in line with the heavy diesel before
going to storage.
The heavy diesel withdrawn from column 10C1 is sent to stripping column 10C4 and stripped using
saturated steam (VS 3800C and approximately 4bar) then passes through exchangers 10 E12 and 10
E7 to release the calories then passes through the aero-condenser 10A5, goes into the tank 10 B4 is
finally mixed in line with the heavy diesel and is sent to storage thanks to the pumps 10P4 A/B.
Descriptive diagram of the path of heavy and light diesel from 10C3 and 10C4 to stock
The distillate withdrawn from column 10C1 is sent to stripping column 10C5 and stripped using
saturated steam (VS 380oC and approximately 4bar) then passes through exchangers 10
E30/E31/E32/E33 to yield the calories before to go to stock C53/C54.
Descriptive diagram of the journey of the distillate from the 10C5 to the stock
The residue does not pass through a stripping column but is stripped at the bottom of the 10C1
column using saturated steam (VS 3800C and approximately 4bar), and to minimize the overheating
which could lead to cracking, the quench residue which functions as a reflux since it also regulates
the temperature (360 OC max) at the bottom of the column.
Descriptive diagram of the journey of the distillate from the 10C5 to the stock
DIAGRAM OF THE ATMOSPHERIC DISTILLATION UNIT (U 10)
II. HEAD ESSENCES HYDROTREATMENT UNIT (UNIT 20)
1. ROLE
The role of the hydrotreating unit is to rid the overhead gasolines of sulphurous, oxygenated,
nitrogenous, metallic compounds and mercaptans.
2. OPERATING PRINCIPLE
Unit 20 is the hydrotreating unit (HDT) for the gasolines at the head of the atmospheric distillation, it
is composed of a certain number of pieces of equipment which allow the efficient treatment of the
gasolines:
- 20 P1 A/B pumps
- 20 E1 C/B/A/D exchangers
- The 20 F1 oven
- The 20 R1 reactor (vertical capacity of 23 m3)
- 20 E1 D/A/B/C exchangers
- The 20 A1 air condenser
- Balloons 20 B1 (17.2 m3), 20B2 (Capacity 1.8 m3)
- The 20 K1 A/B compressor
The 20 P1 A/B pumps draw in the bud essences (outgoing from 10C1) contained in the 10B2 at 2.3
bars and pump them back at around 55 bars into the preheating train to save calories. The
preheating train consists of a series of exchangers, 20 E1C, 20 E1B, 20 E1A, 20 E1D, before the arrival
of the charge in the furnace, it undergoes two injections of hydrogen. The first so-called recycle
hydrogen injection (coming from compressor 20K1) takes place before the feed enters exchanger 20
E1C and the second so-called make-up hydrogen injection (coming from 50K1) takes place between
the exchangers 20 E1C
and 20 E1Bs. Hydrogen and gasoline mix in the preheating train (240 oC) before entering the furnace
on 20F1 by two passes.
The temperature at the inlet of the reactor must be monitored because the rise in the reaction
temperature causes
- the increase in the rate of desulphurization up to a certain threshold
- increased cracking of the light hydrocarbon charge, and coking on the catalyst.
Note that it is preferable that the charge has reached its dry point before entering the 20F1 furnace.
In the 20F1, the charge is heated to 300-310°C, it then enters the 20 R1 reactor where the
desulfurization and other reactions (hydrodeoxygenation, hydrodenitrogenation,
hydrodemetallization) occur and are accelerated thanks to a catalyst made from cobalt and
molybdenum (CO–MO).
. These reactions release heat which raises the temperature of the effluent (petrols + various gases
resulting from the reactions) to 312°C at the outlet of the reactor. The charge leaving the furnace
enters at the top and exits at the bottom.
After 20R1, the effluent goes into the exchange train (20 E1 D/A/B/C) to yield calories to the load and
then it is cooled by two air condensers 20A1A/B to fall back into a separator drum 20B1.
Intervening reactions:
Hydrodesulfurization Mercaptans: RSH + H2 R -- H + H2S
Sulphide hydrodesulphurization: RSR’ + 2H2 R -- H + H2S + R’H
Hydrodeazoation: R – NH2 + H2 R – H + NH3
Hydrdeoxygenation: R–OH + H2 R–H + H2O
Hydrodemetallization:
Table summarizing raw inlet and outlet temperatures (Pulpitreur 10-09-13)
Equipment Inlet temperatures Outlet temperature
Exchanger 20 E1C 0C 0C
Exchanger 20 E1B 0C 0C
Exchanger 20 E1A 0C 0C
Exchanger 20 E1D 0C 251 0C
Furnace 20 F1 251 0C 315 0C
Reactor 20 R1 315 0C 312 0C
Air condensers 20A1A/B 0C 36 0C
Balloon 20 B1 45 0C 0C
DIAGRAM OF THE HEAD ESSENCE HYDROTREATMENT UNIT (UNIT 20)
III. STABILIZATION AND FRACTIONATION OF ESSENCES (UNIT 30)
1. ROLE
This unit has the role of stabilizing and fractionating the total desulfurized gasoline from unit 20.
2. OPERATING PRINCIPLE
Unit 30 is a unit composed of equipment taking part in the process of stabilization and fractionation
of species, we can mention:
- Balloons 30B1 (Capacity 5.295 m3), 30B2 (Capacity 5.24 m3), 30B3 (Capacity 12 m3).
- Pumps 30P1, 30P14, 30P6, 30 P2, 30 P3
- Exchangers 30 E1, 30 E12, 30 E4
- Air condensers 30A1, 30A2, 30 A3, 30 A4
- Columns 30C1 and 30 C2
The total gasoline from unit 20 is collected in the 30 B3 which plays both the role of a buffer tank
between U20 and U30 but also the recontact tank between the fuel gas and the total desulphurized
gasoline (thanks to the static mixer) because it recovers the heavy fractions which risk being lost in
the fuel gas network during the degassing of the head balloon 30B1 to return them to the balloon
30B3, and then conveyed by the pumps 30 P6A/B before being preheated by a train of feed/effluent
exchangers 30 E1A/B/C, then injected into the debutanizer the 30C1 (binary column) at
approximately 210-2200C and at 12 bars to be stabilized there (freed from the light fractions C1, C2).
The light fractions C1, C2, C3, C4 come out at the head of column 30C1 and are partially condensed in
a battery of four air condensers (the 30A1 A/B/C/D), to fall back into the head flask (30B1) in the
form of LPG. At the exit of 30B1, part of the LPG serves as a reflux towards the top 30C1 and the rest
goes towards unit 40 (the gas plant).
The stabilized total gasoline obtained at the bottom of the column yields heat in the exchange train
to the total gasoline around 30C1 and can then take up calories in the 30E4 before heading to the
gasoline splitter (30C2), to be divided into light and heavy essence.
The light gasoline is obtained at the head of 30C2 and is condensed in the aerocondensers 30 A2 A/B
to fall back into the head tank (30B2). At the exit of 30B2, part of the light gasoline serves as a reflux
to the top 30C2 and the rest goes to the stock (B21).
The heavy gasoline obtained at the bottom of the column is split in two; a part goes to unit 50
(catalytic reforming) via the 30E4, to be transformed there into better quality gasoline for
automobile consumption (improvement of the octane number, reformat) and the rest goes to stock
(B22 and B26 ) passing through the 30A4 A/B to be cooled there.
Equipment Inlet temperature Outlet temperature
Balloon 30 B3 36 0C 44 0C
Exchanger 30 E1C 44 0C ……..0C
Exchanger 30 E1B …….0C ……….0C
Exchanger 30 E1A 0C 138 0C
Column 30 C1 138 0C 0C
Air condensers 30 A1A/B/C/D 138 0C 70 0C
Column 30 C2 70 0C 208 0C
Air condensers 30 A2A 74 0C 74 0C
Tank 30B2 30 0C 30 0C
Aerocondensers 30A4 134 0C 134 0C
DIAGRAM OF THE ESSENCE STABILIZATION AND FRACTIONATION UNIT (UNIT 30)
IV. LIQUEFIED GAS FRACTIONATION UNIT (UNIT 40)
1. ROLE
The role of the liquefied gas fractionation unit is to separate the liquefied gases C3, C4 from the
gases of the fuel gas network C1, C2.
2. OPERATING PRINCIPLE
Unit 40 is the Liquefied Petroleum Gas processing unit (the gas plant). Its purpose is to split the LPG
from the top of the debutaniser (30C1) as well as those obtained by reforming hydrocracking (unit
50) to obtain a "bupro" cut.
The equipment involved in the liquefied gas fractionation process are:
- Columns 40 C1
- Air condensers 40A1 and 40 A2
- Balloons 40 B1 (Cap: 1.9 m3), 40 B2 (4 m3), 40 B3 (1.97 m3), 40 B4 (2.55 m3)
- The 40 E1 exchanger
- 40 P1 A/B pumps
The feed to be fractionated in unit 40 comes from the catalytic reforming unit (U50 bottom 50B4)
and the gasoline stabilization and fractionation unit
(U 30 bottom 30 B1 )
This fractionation is carried out in a binary tower (40 C1) where at the head we have light fractions
composed of methanes, ethanes and a part of the propanes so a part is sent to the fuel network and
the other is used as reflux conveyed in the column 40 C1 using pumps 40 P1 A/B .
At the bottom of the column we have bupro which is a mixture of approximately 85% butane and
15% propane, note that part of the bottom of the column is used for reboiling and the other goes
towards the washing and drying phases.
The Treatyment of liquefied gases breaks down into two phases:
Treatment of the 40C1 column head section:
It is carried out at the top of the 40 C1. The operation consists of removing the lightest fractions (C1,
C2 and part of the C3) so as to obtain a vapor pressure of 7.5 bars for the finished product. In this
first phase, the product is also rid of the traces of H2S that it still contained, it passes through the air
condenser 40A2 before going to the balloon 40B2.
Treatment and washing of the butane - propane column bottom product.
In the second phase of the treatment, the bupro passes through the caustic soda (bubbling), in the
40B2 where the H2S and the residual mercaptans are retained.
2 NaOH + H2S Na2S + 2H2O
The bupro is then passed through 40 B3 water, where it will get rid of the traces of soda entrained
from the 40 B2.
Na2S + 2H2O 2 NaOH + H2S
The bupro is finally dried with potash (KOH) at 40 B4, to eliminate traces of water entrained with 40
B3.
Bupro is a fuel that is for domestic use. If it contains sulphur, sulfuric acid is formed during
combustion, which is harmful for both the material and the user.
Equipment Inlet temperatures Outlet temperatures
Column 40C1 45 0C 0C
Tank 40B1 56 0C 68 0C
Balloon 40 B2 32 0C 0C
Balloon 40 B3 0C 0C
Balloon 40 B4 0C 0C
DIAGRAM OF THE LPG UNIT 40 FRACTIONATION UNIT
V. EQUIPMENT AND CHARACTERISTICS
The tables below summarize the equipment and their characteristics in units 10, 20, 30, 40
1. Balloons
TANKS ROLE TEMPERATURE (0C) PRESSURE (Bars eff)
10 B1 Desalter 180 14
10 B2 Head Ball (10C1) 142 3.35
10 B3 Light diesel coalescer 78 13.2
10 B4 A/B Heavy diesel coalescer 78 12.6
10 B5 Temperate water buffer tank 128 2.5
10 B6 Decoking 400 ATM
20 B1 Separator 133 36.3
20 B2 Lead Ball (20C1) 133 3.35
20 B3 Decoking 400 30 B1 Reflux flask and stabilization 103 14.2
30 B2 Gasoline Stripper Reflux 101 2.5
30 B3 Recontact Balloon 133 13.4
30 B4 Flash of capacitors 166 3.5
40 B1 Propanizer reflux 76 26.2
40 B2 Washing with soda 68 27
40 B3 Washing with water 68 27
40 B4 Potash dryer 68 27
2. Columns
FUNCTION COLUMN
10 C1 Atmospheric column
10 C2 Stripper Kerosene
10 C3 Stripper light diesel
10 C4 heavy diesel stripper
10 C5 Distillate Stripper
30 C1 Gasoline stabilization
30 C2 Fuel Splitter
40 C1 Depropanizer
40 C2 Distillate Stripper
3. Ovens
OVEN HEAT RELEASED (Kcal/h) PRESSURE (Bar eff)
10 F1 - 20 F1 3.5 30
4. Reactors
REACTOR ROLE CATALYST TEMPERATURE (0C)
20 R1 Gasoline desulfurization MO-CO 290 - 315
5. Compressor
COMPRESSOR ROLE SUCTION PRESSURE (bar) DISCHARGE PRESSURE (bar) FLOW RATE (m3/h)
20 KI For recycling hydrogen in the unit 20 30 36 127
6.Aero
MARKERS Aero PRODUCT TYPE SURFACE (m2) HEAT EXCHANGED (106xKcal/h)
10 A1 A Aero-condensers Total overhead gasoline vapor
10C1 14.1 10 A1 B
10 A1 C
10 A1 D
10 A1 E
10 A1 F
10 A1 G
10 A1H
10 A2 Air cooler RCS 196 1250
10 A3 Aero-coolant Kerosene 173 4941
10 A4 Air cooler Light diesel 238 54.55
10 A5 Air cooler Heavy diesel 257 43364
10 A6 A Temperate WATER air cooler - 10 A6 B
10 A6C
10 A6 D
20 A1 A Aero-condensers Gasoline Total desulfurized 4924 2.82
20A1B
30 A1 A Air condensers Gas (C4, C3, C2, C1) from the head of
column 30C1 - 30 A1 B
30 A1 C
30 A1 D
30 A2 A Aero-condensers Light petrol vapor from
head 30C2 - 4.22
30 A2 B
30 A3 A Air cooler Light overhead petrol 30B2 851 0.335
30 A3 B
30 A4 A Air cooler Heavy long-distance gasoline 30C2 3020 1,992
30 A4 B
40 A1 A Air condensers Gas (C3, C2, C1) from the top of the column 40C1 787 0.171
40 A1B
40 A3 A Bottom air cooler BUTANE 40C1 - 40 A3 B
7. Push-ups
Markings Pump Location Product Drive Nominal Flow (m3/h) Minimum Flow (m3/h) Discharge
Pressure
10MEP1A Desalter side towards crude tank Cold crude Electric motor 303.9 151.95 21
10MEP1B Desalter side
to crude tank Cold crude Electric motor 303.9 151.95 21
10MEP2A Desalter output Hot crude Electric motor 338 169 32.4
10MEP2B Desalter output Hot crude Electric motor 338 169 32.4
10P3 Desalter side
to crude tank Ambient light crude Electric motor 150 75 5
10P4A Bottom 10C1 unit side 30 Heavy naphtha Electric motor 321.1 160.55
10PTP4B Bottom 10C1 unit side 30 Heavy naphtha Turbine 321.1 160.55
10MEP5A Behind the exchangers 10E6/7 Kerosene Electric motor 433 216.5
10MEP5B Behind the
exchangers
10E6/7 Kerosene Electric motor 433 216.5
10MEP6A Balloon bottom
head 10B2 Kero to stock Electric motor 75.6 37.8
10MEP6B Balloon bottom
head 10B2 Kero to stock Electric motor 75.6 37.8
10MEP7A Bottom 10C1 side
unit 30 Light gas oil Electric motor 50 25
10MEP7B Bottom 10C1 side
unit& 30 Light gas oil Electric motorrisk 50 25
10MEP8 Behind the
exchangers 10E9 Heavy gas oil Electric motor 260.4 130.2
10MEP9 Bottom 10C1 side
Unit 30 Heavy gas oil Electric motor 45.4 22.7
10MEP10A Bottom 10C1 side
Unit 30 Atmospheric residue Electric motor 157.4 78.7
10TP10B Bottom 10C1 side
Unit 30 Atmospheric residue Turbine 165.3 82.65
10MEP12A Behind
exchangers
10E30/31/32/33 Temperate water Electric motor 179.5 89.75
10TP12B Behind
exchangers
10E30/31/32/33 Temperate water Turbine 179.5 89.75
10P14 Desalter side
to tank Fuel Oil Slops heavy/light Electric motor 30 15
10P16X Bottom desalter
10B9 Antiscale
(demulsifier)
ambient Electric motor 0.197 0.0985
10P17X Bottom desalter
10B9 Antiscale
(demulsifier)
ambient Electric motor 0.0055 0.00275
10P18X Unit 70, balloon
soda 10B11 Ambient soda Electric motor 0.353 0.1765
10P19X Unit 70, balloon
soda 10B11 Ambient soda Electric motor 0.1285 0.06425
10P20X Bottom 10C1, balloon
anticorrosive
10B13 UNICOR
Ambient Electric motor 0.003 0.0015
10P21X Bottom 10C1, balloon
of UNICOR anticorrosive
Ambient Electric motor 0.003 0.0015
10MEP22 Desalter side
to tank Fuel Oil Total gasoline Electric motor 31.8 15.9
10MEP30 Distillate Electric motor 51.4 25.7
10MEP31 Behind the
exchangers
10E6/7 Heavy gas oil Electric motor 829.5 414.75
10MEP32 Balloon bottom
head 10B2 Distillate Electric motor 36.2 18.1
10P501
Diesel fuel analyzer Electric motor 0
20MEP1A Head tank bottom, 10B1 Charging gasoline Electric motor 116.3 48.6
20MEP1B Bottom head tank, 10B1 Charging gasoline Electric motor 116.3 48.6
20MEP2 Fire wall side Washing water Electric motor 30
30MEP1A Below the
Platform of
unity ball
30/40 Liquefied petroleum gas
ambient Electric motor 45.65
30MEP1B Below the
Platform of
unity ball
30/40 Liquefied petroleum gas
ambient Electric motor 45.65
30MEP2A Below the
Platform of
unity ball
30/40 Light gasoline Electric motor 56.6
30MEP2B Below the
Platform of
unity ball
30/40 Naphtha Electric motor 57.2
30MEP3 Below the
Platform of
unity ball
30/40 Naphtha Electric motor 56.65
30MEP5 Analyzer side
Diesel naphtha Ambient Electric motor 37.5 5.82
30MEP6A Below the
Platform of
unity ball
30/40 Gasoline total
desulfurized Electric motor 75.8 17.21
30MEP6B Below the
Platform of
unity ball
30/40 Gasoline total
desulfurized Electric motor 75.8 17.21
30P12 Below the
Platform of
unity ball
30/40 Light gasoline Electric motor 73 6.7
30MEP14A Lance side
monitor No 2 Gas Liquefied petroleum Electric motor 14.3 27
30MEP14B Lance side
monitor No 2 Gas Liquefied petroleum Electric motor 14.3 27
40MEP1A Below the
Platform of
unity ball
30/40 Ambient butane Electric motor 6.45 27.1
40MEP1B Below the
Platform of
unity ball
30/40 Ambient butane Electric motor 6.45 27.1
40MEP2 Below the
Platform of
unity ball
30/40 Water from 40 B3 Electric motor 1.05 16.37
40MEP3 Below the
Platform of
unity ball
30/40 E.D Electric motor 1.005
40MEP4 Base SAS Soda Electric motor 56.65
8. Exchangers
EXCHANGERS ROLE SURFACE (m2) HEAT EXCHANGED (106xKcal/h) GRILLE FUNCTION BEAM
FOUNCTION
10 E1 raw load preheating and
RCS cooling 242.4 1.129 Gross discharge
10 MEP1 A/B R.C.S discharge 10 P4 A/B
10 E2 raw load preheating and
kerosene cooling to
stock 98.9 2.452 Kerosene
pushback 10
10MEP6 A/B Gross shell output 10 E1
10 E3 raw load preheating and
cooling of light diesel to
stock 44.6 1.101 Light diesel
grille outlet
10 E6 Raw beam output 10 E2
10 E4 A raw load preheating and
RCM cooling 896 7.277 R.C.M output
grille 10 E4 B Gross beam exit 10 E4 B
10 E4 B raw load preheating and
RCM cooling 896 7.277 R.C.M output
beam 40 E1 Raw output beam 10 E32
10 E5 A raw load preheating and
cooling of the residue towards
stock 1063 4.745 Outgoing residual
grille 10 E9 A Gross beam exit 10 E5 B
10 E5 B raw load preheating and
cooling of the residue towards
stock 1063 4.745 Outgoing residual
grille 10 E5 A Gross discharge 10 MEP 2
A/B
10 E6 2nd crude oil preheating train
diesel charging and cooling
light to stock 321.4 1.466 Light diesel
pushback 10
MEP7 A/B Raw beam output 10 E5 A
10 E7 2nd crude oil preheating train
diesel charging and cooling
heavy to stock 357 2,228 Heavy diesel
pushback 10
MEP9 Raw beam output 10 E5 A
10 E9 A 2nd crude oil preheating train
load and residue cooling 1.09 Residual outlet
grille 10 E9 C Gross beam exit 10 E7
10 E9 B 2nd crude oil preheating train
loading and cooling of the residue to stock 1320 7.965 Residue
refuse 10P10A/B Gross beam output 10 E 9 C
10 E9 C 2nd crude oil preheating train
loading and cooling of residue to stock 1320 7.965 Residue output
grille 10 E9 B Gross beam exit 10 E35 A
10 E10 TRIMCOOLER for cooling the
Residual for storage 454.4 6.104 Residual out
grille 10 E5 B Temperate water discharge
10 P12 A/B
10 E12 Engine cooling exchanger
GOH for storage 53.2 1.035 Heavy diesel
grille outlet
10 E7 Desalination water
discharge 70 MEP1 A/B
10 E14 TRIMCOOLER for cooling the
Kerosene for storage - - Kerosene out
10 MEA3 Water service
10 E30 2nd crude oil preheating train
charging and cooling
DISTILLATE for storage - 2.05 Distillate
pushback 10
MEP 30 Raw output beam 10 E35 A
10 E31 1st crude oil preheating train
charging and cooling
DISTILLATE for storage - 1.6 Distillate output 10
E30 Raw beam output 10 E6
10 E32 1st crude oil preheating train
charging and cooling
DISTILLATE for storage - 1.46 Distillate output
beam 10 E31 Gross output beam 10 E3
10 E33 TRIMCOOLER for engine cooling
DISTILLATE in storage Distillate out
grille 10 E32 Temperate water discharge
10 P12 A/B
10 E34 Kerosene reboiler for the
stripping column 10C2 - 2 Kerosene outlet
bottom 10 C2 R.C.I discharge 10 MEP 8 /
10 MEP 31
10 E35 A 2nd crude oil preheating train
RCI cooling load - 1.07 R.C.I output
beam 10 E34 Gross output beam 10 E35 B
10 E35 B 2nd crude oil preheating train
RCI cooling load - 1.07 R.C.I output
grille 10 E35 A Gross output beam 10 E35 A
10 E35 C 2nd crude oil preheating train
RCI cooling load - 1.07 R.C.I output
grille 10 E35 B Gross beam exit 10 E31
/10 E9 A
20 E1 A preheats gasoline for
desulfurization and cooling of
gasoline after desulfurization 9.197 9.48 Charge liq. +H2
recycle exit cl.20E1B Effluents exit bundle 20
E1 D
20 E1 B preheats gasoline for
desulfurization and cooling of
gasoline after desulfurization 9.197 9.48 Charge liq. exit
cl.20E1B +H2
recycle Effluents output beam 20
E1A
20 E1 C preheats gasoline for
desulfurization and cooling of
gasoline after desulfurization 9.197 9.48 Charge liq.
pushback 20
MEP1 A/B Effluents output bundle 20
E1 B
20 E1 D preheats gasoline for
desulfurization and cooling of
gasoline after desulfurization 9.197 9.48 Charge liq. +H2
rec. exit
cal.20E1A Effluent outlet 20 R1
30 E1 A preheats desulfurized gasoline
for stabilization (debutanization) 131.3 3.2 Bottom exit 30 C1 Beam exit 30 E1 B
30 E1 B preheats desulfurized gasoline
for stabilization (debutanization) 131.3 3.2 Grill outlet
30 E1 A Beam output 30 E1 C
30 E1 C preheats desulfurized gasoline
for stabilization (debutanization) 131.3 3.2 Grill outlet
30 E1 B Bottom outlet 20 B1 or discharge.
30 P6 A/B
30 E3 A Heavy Gasoline Reboiler by the
RCM (column bottom 30C2) 165.1 3.58 Bottom 30 C2
(reboiling) R.C.M discharge 10 MEP 5
A/B
30 E3 B Heavy Gasoline Reboiler by the
RCM (column bottom 30C2) - - Bottom 30 C2
(reboiling) Steam V.M
30 E4 stabilized ESS preheating for
SPLITTER load 30C2 60 0.87 Calender outlet
30 E1 C Discharge 50 MEP1 A/B
30 E12 Stabilized gasoline reboiler for
column 30C1 - 5.56 Bottom 30 C1
(reboiling) R.C.I grille outlet 10 E35
VS
40 E1 BUTANE Reboiler
(column bottom 40C1) 17 0.481 Bottom 40 C1
(reboiling) R.C.M beam output 30 E3
HAS