1 - Crude Oil Treatment - Separation

SURFACE PROCESSING

A – CRUDE OIL TREATMENT I- SEPARATION © 2007 ENSPM Formation Industrie - IFP Training

PRO01198 – CRUDE OIL TREATMENT - Separation

SEPARATION – Contents 1- Well effluents Generalities 2- Gas/liquid separation -equilibrium calculations -influence of the process recovery rate 3- Separator sizing principles -diphasic vertical separator -diphasic horizontal separator

5- Foaming (difficult gas/liquid separation) Next course: Oil/Water separation PRO01198 – CRUDE OIL TREATMENT - Separation

© 2007 ENSPM Formation Industrie - IFP Training

4- Gas/Liquid Separator different types

1- Well head effluents © 2007 ENSPM Formation Industrie - IFP Training


WELL HEAD EFFLUENTS

GAS WELLHEAD EFFLUENTS

OIL WATER FORMATION SAND AND SILT COLLOID STATE CLAY

MINERAL CRYSTALS NaCl CaCO3 BaSO4 SrSO4



CORROSION PRODUCT WAXES ASPHALTENES

SEPARATION CHAIN

FOAMS LIQUID DROPLETS IN GAS

WELLHEAD EFFLUENTS

GAS

GAS TREATMENT DEHYDRATION CONDENSATE RECUPERATION

GAS-LIQUID SEPARATION

CONDENSATE WATER

EMULSION INTERMINGLED WATER/OIL

OIL-WATER SEPARATION OPERATIONS SOMETIMES CARRIED OUT in 1 PROCESS EQUIPMENT PRO01198 – CRUDE OIL TREATMENT - Separation

EMULSION TREATMENT

EMULSION FREE WATER

WATER


export crude

SOURCE OF WATER

WATER AND OIL ZONES IN RESERVOIR

OIL OIL



* Active Water Reservoir * Water Injection : Injection of 1-2 volumes of water Production of 1-5 volumes of water per oil volume * Faulty Cementing Job

SOURCE OF SALT RESERVOIR WATER SALT

INJECTED WATER (SEA WATER)

*HASSI MESSAOUD : CAMBRIEN WATER 370g/l Low Water Cut 0,1%

HIGH SALT CONTENT SALT CONTENT 370 mg/l

*If Salt Content>10mg/l , Reservoir Water INGRESS *Sometimes HIGH SALT CONTENT without Water EAST BAGDAD As much as 265ppm of salt ***

Produced Water Not Detected; only salt content is measured



* Same for Hassi Messaoud - Fateh - ABK -Zadco This Phenomenon is limited in Time

OIL , BSW and GOR EVOLUTION WITH TIME Production 3

difficulty to design separation equipment

106 m3 / an

OIL

2

BSW

GOR

%

1

1

300

20

200

10

100

BSW 2

3


4

5

6

7

8

9

10

11

12

YEARS


GOR

30

CONTRACTUAL WATER AND SALT CONTENTS

CRUDE OIL MARKETING

AGREEMENT

$

Business is business!!

$

PRODUCERS TRANSPORTERS REFINERS

TRANSPORTERS : LIMITATION FOR WATER CONTENT *PIPELINE

BSW <= 0.5% NO FIXED CONSTRAINTS - ACCIDENTAL CONTAMINATION - LOAD ON TOP CONTAMINATION


BUT


*BY SEA

- PIPE OVER LOADING - CORROSION ( WATER + SALT )

CONTRACTUAL WATER AND SALT CONTENTS

EUROPEAN REFINERIES 1 ELECTROSTATIC DESALTER SALT CONTENT <5mg/l * SCALE DEPOSIT INSIDE EXCHANGERS * DISTILLATION UNITS CORROSION * RESIDUAL QUALITY DEGRADATION 95 % EFFICIENCY INLET INLETSALT SALTCONTENT CONTENT<<100 100mg/l mg/l PRODUCTION FIELD SPECIFICATIONS Salt...100 mg/l

TRANSPORT :

Salt...60 mg/l

BSW BSWin inProduction ProductionFields Fields<<0.5 0.5% % PRO01198 – CRUDE OIL TREATMENT - Separation

Water....0,2% Water....0,5%


REFINERY :

DEHYDRATION/DESALTING

DEHYDRATION TO WITHDRAW WATER DISPERSED IN CRUDE STRESSING THE WATER CONTENT

DESALTING TO GET THE SALT SPECIFICATION WHEN THIS IS NOT THE DIRECT RESULT OF COMPLYING THE WATER SPEC.



DESALTING IS A DEHYDRATION TRT SET PREVIOUSLY WITH WASH WATER SOFTER THAN RESERVOIR WATER

DEHYDRATION/DESALTING With Reservoir Water at 350 g/l expressed as NaCl equivalent 0.1 % of Water Content

350 mg/l ( 123 PTB ) Salt Content

Salt Content < 60 mg/l

Water Content < 0.017 %

SALINITY IS THE MOST RESTRICTING SPECIFICATION With Reservoir Water at 40 g/l expressed as NaCl equivalent 40 mg/l ( 14 PTB ) Salt Content

Salt Content < 60 mg/l

Water Content < 0.15 %

WATER CONTENT IS THE MOST RESTRICTING SPEC. PRO01198 – CRUDE OIL TREATMENT - Separation


0.1 % of Water Content

2- Gas/liquid separation



GAS/LIQUID SEPARATION - Generalities

Hydrocarbon reservoir : at reservoir conditions, generally one monophasic fluid at surface conditions (P &T decrease), different components appear : monophasic polyphasic (gas + liquid) hydrocarbon gas condensation of heavier hydrocarbons liquid water vapour liquid water



THERMODYNAMIC BEHAVIOUR

TREATMENT UNIT

AIM OF A TREATMENT UNIT to recover all the different constituents Process specific to each development to treat oil so that it is free of gas to produce a gas as dry as possible (no water nor heavy hydrocarbons) to remove water (and solids) from oil



to remove oil and solids from water (Water Treatment specific courses)

Hydrocarbon production scheme Pw

Pc Separation Storage

Shipping

Ps

Pr

Pr


Pr: Pf:

Reservoir pressure Bottomhole flowing pressure Pw: Wellhead pressure Pc: Choke pressure Ps: Processing pressure


Pf

Reservoir

Phase diagram

P Pr Liquid Pf Bubble Point

100 %

30 %

Pc

Ps


5%

1%

0% mole % liquid T


15 %

0

Vapour

Pw

METHANE - ETHANE MIXTURE PHASE DIAGRAM



GAS PHASE ENVELOPPE SHAPE VERSUS GAS COMPOSITION



1. Flash process

P1 V1 T1

P2 V2 T2

with P1 > P2

at Constant composition If T constant = flash liberation P1 V1 T1

P2 V2 T1

P1 > P2

P2 V2 T2

P1 > P2 T1 > T2

If T varies = flash separation

G1 L1 P1 T1 PRO01198 – CRUDE OIL TREATMENT - Separation

G2 L2 P2 T2


P1 V1 T1

2. Differential process P1 > P2 G1 L1

GS Gi Li

P1 T1

G2 L2 P2 T2

total composition varies : there is draw off

If T = constant = differential liberation © 2007 ENSPM Formation Industrie - IFP Training


3. Composite process : combination of the two Separators

Reservoir

Storage

PG TG

PF TG

P1 T1

P2 T2

Pa Ta

L

G L

G1 L1

G2 L2

GS LS

Differential Liberation (T cst)

Flash

Flash

Flash

P PG PF

P2 Pa

T Ta


T2

T1

TG


P1

OPTIMAL SEPARATION PRESSURE IN HYDROCARBON PRODUCTION FIELDS IS AN APPLICATION OF PHASE EQUILIBRIUM IN THERMODYNAMICS

AMOUNT OF LIQUID RECOVERED IS DEPENDENT OF THE COMPOSITE PROCESS

SEPARATION EFFICIENCY



YIELD (R) = final stock tank oil mass / mass of hydrocarbons entering the processing unit

Influence of the Process Recovery rate P 1

Pb

Liberation 3

1

Separation 2

15°

TG

T

Rs FROM PVT LAB EXPERIMENTS

Differential Rs =

V gas produced V oil at Pb


Pb

P


Flash

Influence of the Process Recovery rate

QUANTITIES OF FREE GAS ARE MORE IMPORTANT IN FLASH LIBERATION THAN IN DIFFERENTIAL LIBERATION SIMILARLY, VOLUME OF LIQUID IS GREATER IN A DIFFERENTIAL PROCESS THAN IN A FLASH PROCESS THE RELATIVE DIFFERENCE BETWEEN THE TWO CURVES DEPENDS ON THE NATURE OF THE OIL : SLIGHT FOR HEAVY OILS AND GREATER FOR VOLATILE OILS

the higher the number of separation stages, the greater the liquid but P at 1st stage is governed by well head P (i.e. reservoir P) number of stages is a compromise between costs of installation and liquid recovery



recovery

Influence of the process Recovery rate Application / Field One stage G L Pi T1

Flash liberation

G L Ps T1

max gas & min liquid

Several stages G

G

G

L

L P2 T1 Separators

L P3 T1

L Ps T1 Storage

P1 T1

in each separator : flash liberation but the whole chain of separators represents a differential separation max of liquid recovery for an infinite number of separation stages



G

Separation pressure at the different stages Rule of thumb n-1

R=

P sep. HP P storage

n = number of stages + storage Examples GOR < 20 m3/m3


1° :10-20 bara 2°: 2-6 bara 3°: Storage

GOR > 200 1°: 20-40 bara 2°: 5-15 bara 3°: 2-5 bara 4°: Storage


GOR < 150 m3/m3

1°: 3-7 bara 2°: Storage

EXAMPLE OF APPLICATION

PALANCA FIELD (ANGOLA)

Separation efficiency = final stock tank oil mass / mass of hydrocarbons entering the processing unit

at P = 25, 20, 15 & 10 bar at T = 105°C, 90°C, 75°C



Determination of the optimal P & T and number of separation stages to get the higher separation efficiency

PALANCA separation – output 2nd stage Sep. Efficiency (%) 76.5 75° C

76 75.5 75

90

74.5 74 73.5

105

72.5 0

5


10

15

20

25 Pressure (bars)


73

PALANCA separation – output 3rd stage Sep. Efficiency (%) 77.5 77 76.5 75° C

76 75.5 75

90

74.5 74 105

73 0 3 6 Low pressure separator pressure


9

12

15 Pressure (bars)


73.5

PALANCA separation – output 4th stage Sep. Efficiency (%) 77.5 75° C

77

76.5

76

90

75.5

74.5

105

3 0 6 Medium pressure separator pressure


9

12

15 Pressure (bars)


75

PALANCA separation – output T=75°C Output (%) 78

77.5 4 stages

77

significant gain between 2 & 3

76.5

less gain between 3&4 ECONOMICS COMPROMISE

2 stages

75.5 0

5


10

15

20

25 Pressure (bar)


76

3 stages

Influence of separation temperature EFFECT ON RECOVERY (

)

+

Temperature • •

Liquid Economy

Average

•

Water

• •

Gas H2S treatment

High

•

Gas

Price

in general, the lower the T the higher the liquid recovery (but other parameters interfere on final Process T chosen : e.g. oil/water separation which is enhanced by high T°C) PRO01198 – CRUDE OIL TREATMENT - Separation


Low

-

Influence of separation T & P : example 1

ASHTART Gas

13b - 110 °C

Gas

1b - 85 °C Oil Gas

5b - 40 °C

Gas

1b - 35 °C



GAIN 9 % OIL at lower T

Oil

Influence of separation T & P : example 2 BREME Flare Gas

4b 40° C 1b

Oil

Flare

3.5 b 30° C Gas

4b 40° C

GAIN 2.6 % OIL from flare gas recovery PRO01198 – CRUDE OIL TREATMENT - Separation

Oil


1b

3- Separator sizing



Sizing of a separator

INCREASING COMPLEXITY OF FIELD INSTALLATIONS WITH THE AIM TO MAXIMISE RECOVEY AND OPTIMISE ALL PRODUCTION UNITS

INTRODUCTION TO GENERAL PRINCIPLES AND METHODS OF SIZING AND TYPICAL VALUES

SPECIFIC INSTALLATIONS AS HEATER-TREATER, CYCLONIC SEPARATORS, etc. ARE DETERMINED BY MANUFACTURERS © 2007 ENSPM Formation Industrie - IFP Training


Sizing of a separator

DIMENSIONS FOR GAS AND LIQUID FLOWRATES ARE CALCULATED SEPARATELY

FOR GAS FLOWRATE, SPEED LIMITED TO PREVENT GAS FROM ENTRAINING DROPLETS OF LIQUID smallest diameter possible

FOR LIQUID FLOWRATE, RETENTION TIME SIZE TO ENSURE THAT THE GAS IS COMPLETELY RELEASED FROM IT



DEPENDS ON OIL CHARACTERISTICS

Sizing of a separator 1

Basic data Gas : Flow rate - composition - specific mass Oil : Flow rate - composition - specific mass Retention time

2

Sizing for gas Sizing = passage cross-section Passage cross-section = f (limit velocity gas) Limit velocity gas = liquid not drawn with it Sizing for liquids Sizing = f (retention time) Retention time = time needed for degassing Retention time = f (oil characteristics)



3

Sizing of a separator Vertical separator

GAS

Aim : PREVENT WATER BEING DRAWN ALONG A at

P T

R

D (Ø) L

Liquid

liquid

ΠD3 P= 6 weight

R= K

ΠD2

4

V2

A=

V

aerodynamic force

P>A+R

V
fixed D limit = 20 µm 1 Kv = f ( GOR PRO01198 – CRUDE OIL TREATMENT - Separation

ΠD3

6

Vg

buoyancy

D

L- V V

L ) = m/s V

max speed not to carry over D


Condition :

Gas

P Lg

V V (velocity)


GAS

Calculation of V (P and T) from M • Let M = 30 (0° C - 1013 mb) o=

30 22.4

MP ZRT

Kg/m3 =

• If T = 50° C and P = 20 bar V= ox 30 22.4

x

20 x 1.013

T0 T

x

273 x 323

A few values of Kv • Flare drum (horizontal) • Column head separator (horizontal) • Compressor suction (vertical) PRO01198 – CRUDE OIL TREATMENT - Separation

0.04 m/s 0.07 m/s 0.04 m/s

1 Z

1 x 0.93

= 24 kg/m3


=

P P0

Separator value of Kv in m/s versus GOR




LIQUID

Transit time through the vessel Concerns water and oil (Gas : pm) T:transit time

T=

V Q

=

Π D2 4

x

h Q

T:transit time fonction of decantation time and retention time



VERTICAL Separator / Liquid : liquid sizing

Gas Outlet

GAS

Decantation time refers to liquids

Feed

Water droplet Oil outlet OIL Water outlet

Gas bubble Oil droplet



WATER


LIQUID

Decantation time STOKES' law

V=

g D2 ( L - V) 18 µ

D=O.1 mm

(around 20 to 30 µm in general)

note : Decantation time is very dependant of the crude and water characteristics ( emulsions) PRO01198 – CRUDE OIL TREATMENT - Separation


V = settling velocity of the liquid droplet D = diameter of the droplet L = specific gravity of droplet V = specific gravity of the gas at P&T g = gravitational acceleration µ = viscosity of the continuous phase


LIQUID

Retention time (practical reference) corresponds to the value obtained by taking the volume measured between the mean level and the low level, where the mean level usually is located in the middle of the drum Often varies with the crudes from 2" to 5" in most cases but can reach 10" or even 30" or 60" for "problematic" crude, i.e. heavy oils or acid crudes © 2007 ENSPM Formation Industrie - IFP Training


Sizing of a separator Vertical separator Common practices • Gas passage velocity : V critical = 0.048 • Internal diameter :

D=

L- G G Q 900. Π . V


D in m Q in m3/h V in m/s


• Height of separator : 1.5 < Height/Diameter < 3 • Max. oil level : Hoil < 0.65 D • Low oil level : at 10 inches from the bottom • Retention time Oil + water = 2" to 5" If foaming or high viscosity : 10" (heavy oil ROSPO MARE : 35")

in m/s

Sizing of a separator Horizontal separator Flow straightened cross section

Demister Gas Liquids

Secondary chamber Decantation chamber Horizontal separator

A

Entrainment

Entrainment

P Resultant

Kv horiz. = 1.25 Kv vertical Gravity


Resultant

Gravity


liquid

R

Vertical separator

Sizing of a separator Horizontal separator L

Decantation time D

with Stokes law

l Water Vh

h

Oil droplet

Vwater

=

continuous water height (water)

vh

=

decantation velocity of an oil droplet (rising)

vwater =

displacement velocity of the continuous water phase (horizontal)

l

=

minimum decantation length

t

=

decantation time.



h

Sizing of a separator: Summary

GAS IS THE PRIORITY PARAMETER TAKEN INTO ACCOUNT IN THE DESIGN OF SEPARATORS

LIQUID TRANSIT TIME (often referred as Retention time) IS MORE EMPIRIC AND IS MORE BASED ON EXPERIENCE WITH SAFETY MARGINS MORE OR LESS IMPORTANT



DECANTATION TIME FOR LIQUIDS IS GENERALLY BASED ON LAB EXPERIMENTS

4- Gas/Liquid Separator different types © 2007 ENSPM Formation Industrie - IFP Training


Vertical 2 phase separator Pressure

Safety seal

well adapted

valve Mist extractor Déflector

Oil and gas inlet

for low GOR

Deflector action 1

Pressure gauge

2

Drainage duct Primary chamber

Isolation partition Manhole

Visual level monitor

1. body of separator 2. gas outlet (high point) 3. fluid input

Purge Base


Gas flow Liquid flow

Centrifugal effect in a vertical separator


Oil outlet Decantation chamber

3

Horizontal 2 phase separator

Primary chamber

Settling section

Secondary chamber

Mist extractor

Diffuser Gas outlet

Gas + liquids inlet

Purge

Oil outlet

Chassis

Decantation chamber

Anti-wave partition

Separation partition

well adapted

Liquid

Inlet diffuser PRO01198 – CRUDE OIL TREATMENT - Separation

for high GOR


Gas

High-pressure horizontal separator with liquid retention capacity

gas outlet

Inlet

large capacity high P



liquid outlet

Spherical 2 phase separator

rare Fluids inlet

for very high GOR Deflector

Scrubber

Level regulation

Gas outlet



Oil outlet

Cyclone effect separator Gas outlet

Gas + Liquid inlet



Liquid outlet

Multi-cyclone separator Gas outlet

Multicyclones

Gas inlet

Diffuser

Liquid level

Liquid outlet Secondary drain

Retention volume



Liquid outlet

Other types of gas/liquid separators



Gas SCRUBBER

Mist extractor Sifter



VAPE SORBER

Absorbent material

Porous filters © 2007 ENSPM Formation Industrie - IFP Training


Components of a gas/liquid separator © 2007 ENSPM Formation Industrie - IFP Training


Horizontal 2 phase separator components/internals Settling section Mist extractor Secondary chamber

Primary chamber

Diffuser Gas outlet

Gas + liquids inlet

Purge

Decantation chamber


Separation partition

Anti-wave partition


Chassis

Oil outlet

5- Foaming difficult gas/liquid separation



Foaming Origin • Gas expansion + oil / gas surface tension Theory • Pure liquids do not foam A surfactant is needed Mixtures of isomers in hydrocarbons are surfactants • Foams are unstable (state of least energy)



• The internal viscosity of the oil stabilises the foam, leading to drawing along of the gas (foaming)

FOAMS

– FOAMS are oil + gas "emulsions"

T=15mn



FOAMS – Inconvenience

– INCONVENIENTS : • oil entrainments in gas (affecting scrubbers, flares, compressors protection, gas treatment solvents ...), and gas entrainments in oil ( pump cavitation, later degassing...)



• loss of control of levels in separators

FOAMS – Schematic representation

INTERFACIAL FILM

GAZ

• the speed of drainage is dependant of the viscosity of the oil •the max width is dependant of the liquid interfacial tension © 2007 ENSPM Formation Industrie - IFP Training


FOAMS STABILISATION

• NATURAL SURFACTANTS • ADDED SURFACTANTS (PRODUCTION CHEMICALS) • SOLID PARTICULES • WATER DROPLETS © 2007 ENSPM Formation Industrie - IFP Training


Foaming is dependant on crude characteristics

Tendency to foam API 40 = .825 Increase in % vol. Foam breaking in seconds

API 30 = .876

API > 40

30 < API < 40

API < 30

10 - 20

20 - 40

> 50

30

30 - 60

> 60

BUT • If asphaltene content > 1 %, higher foaming and stability

• The % of water and additives (anticorrosion etc… ) do not appear to have any effect on the phenomenon



• if acid index >0.2 mg KOH/l, lower quantity of foam & higher stability

FOAMS : separation / breaking

•

THE VERTICAL SPEED OF GAS BUBBLES IS HIGH DUE TO THE HIGH DENSITY DIFFERENCE WITH THE OIL (STOKES LAW)

•

GAS BUBBLES FLOCCULATE AT THE SURFACE AND CREATE A "MATTRESS"

•

COALESCENCE BECOMES THE LIMITING FACTOR

– BREAKING WIDTHS ARE MUCH THINNER THAN FOR EMULSIONS PRO01198 – CRUDE OIL TREATMENT - Separation


– THE LIQUID IS DRAINED OUT OF THE INTERFACIAL FILM DECREASING ITS WIDTH UNTIL A MINIMUM VALUE IS REACHED WHERE IT BREAKS

FOAMS TREATMENT

•

IT IS POSSIBLE TO : – increase the breaking width of the foam by adding a chemical – increase the speed of drainage by lowering the liquid viscosity (HEAT) – install separator internals acting on wettability



– use separators equipped with specific cyclonic inlet devices

FOAMS TREATMENT

Treatment

• Mechanical

- Washing - longer time spent in installation

• Chemical

- anti-foam



FOAMS TREATMENTS : anti-foams Chemical Treatment

ANTI-FOAMS Action: • displace the foam stabilizing element from the bubble walls • or cause bubbles to burst locally



Necessary conditions: • be soluble in the foaming system • disperse satisfactorily • have surface tension < that of the foam

FOAMS TREATMENTS : anti-foams

anti-foam additives – MOSTLY USED : SILICONE OILS ( POLYSILOXANES ) – EFFICIENT AT 2/3 ppm (4 to 5 ppm if diluted ) – HAVE TO BE INJECTED UPSTREAM THE SEPARATOR BUT THE CLOSER FROM THE INLET • LOSS OF EFFICIENCY AFTER A CERTAIN PERIOD OF TIME) • LOOSE THEIR EFFICIENCY WHEN TOO MUCH MIXED WITH THE CRUDE

their dosage have to be strictly controlled



THESE PRODUCTS ARE REFINERY CATALYSTS POISONS

FOAMS TREATMENTS : anti-foams

OTHER PRODUCTS :

– Heavy Alcohols, cheap but weak efficiency – fluoro-Silicones, very efficient but expensive

Selection implemented in the Flash Foaming Test (Lab)



• to be used in severe cases

CRUDE OIL FOAMING TENDENCIES

OIL STORAGE

FLASH FOAMING TEST PI

M

TR

NITROGEN BUTANE

TO WATER BATH PROCEDURE

TR


CALIBRATED CYLINDER


ADJUSTABLE CONTROL VALVE ( 35 L/H)

P = 10 BARS with N2 / BUTANE T = 60 ° C 600 CC OIL

FOAMS TREATMENTS : mechanical

Gas

Mist extractor

Gutter separator for foam treatment Diffuser Inlet Inclined plates



Oil





Section X-X



DIXON PLATES

FOAMS TREATMENTS : mechanical Inlet PC (gas) Gas Mist extractor

Gas

LC (water) oil

Oil

Salt water Heating


LC (water)

Water


Burner

Foam treatment by heating in salt water bath

FOAMS - CONCLUSIONS

• FOAMS ARE SIMILAR TO EMULSIONS • HEAVY OILS (viscous) OR ACID/NAPHTENIC CRUDES (natural surfactants) ARE CREATING STRONG FOAMS

• IF NOT, FOAM TREATMENT USUALLY REQUIRES HEAT + CHEMICAL TREATMENT PRO01198 – CRUDE OIL TREATMENT - Separation


• IF FOAMING HAS BEEN ANTICIPATED, OVERSIZING OF SEPARATORS OR SEPARATOR INTERNALS CAN BE CHOSEN TO LIMIT INCONVENIENTS

CRUDE OIL PROCESSING - SEPARATION



Flash liberation Pressure (bars) 300

Yield (R) 250

Bubble curve

98.4

200

100 % 97.2 96 94.4 91.7 88.9

150

85.1

100 80 88.9 %

50

0 0

50


100

TG 150

200

T(° C)


P1

Differential liberation Pressure (bars) 300

250

Initial bubble curve in the reservoir

Elimination of gas

200

Bubble curve at perforations

Yield (R) 100 %

150

95.0 88.1

100

86.2 92 %

83.7

50

0 0

50


100

TG 150

200

T(° C)


P1

Composite liberation Pressure (bars) 300 Initial bubble curve in the reservoir

250

gas elimination

200

Yield (R) 100 %

150 Bubble curve at perforations

Well head

Perforations

91.0 88.9

100

86.7 84.7

90 % 1st stage separation

50

0 0

50


100

TG 150

200

T(° C)


P1

1 - Crude Oil Treatment - Separation

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