How to Size a Separator

8/16/2019 How to Size a Separator

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1

2

3

4

5

5A

5B

5C

5D

66A

6B

6C

6D

Prepared by:

Ajay S. Satpute

Sr. Process Engineer

Ramboll Consulting Engineering, Qatar

INDEX:

Discussion

Nomenclature

References

Standard Separator Sizes as per API

Separator sizing with mist extractor

Three Phase (Gas ‐ Oil ‐ Water) Vertical Separator as per Petroleum and Gas Field Processing

Three Phase (Gas ‐ Oil ‐ Water) Horizontal Separator as per Petroleum and Gas Field Processing

Two Phase (Gas ‐ Oil) Vertical Separator as per API 12J

Two Phase (Gas ‐ Oil) Horizontal Separator as per API 12J

Three Phase (Gas ‐ Oil ‐ Water) Vertical Separator as per API 12J

Three Phase (Gas ‐ Oil ‐ Water) Horizontal Separator as per API 12J

Two Phase (Gas ‐ Oil) Vertical Separator As per Petroleum and Gas Field Processing

Two Phase (Gas ‐ Oil) Horizontal Separator as per Petroleum and Gas Field Processing

Separator sizing without mist extractor


2/14

INDEX

Inlet Nozzle Momentum or Velocity Limit

No Internal Max. Momentum, ρm V2

m ≤1400 Pa

Half open pipe Max. Momentum, ρm V2

m ≤2100 Pa

Schoepentoeter used as inlet device Max. Momentum, ρm V2

m ≤8000 Pa

Gas outlet Nozzle Max. Momentum, ρg V2

g,out ≤4500 Pa

Liquid outlet Nozzle Maximum velocity, 1 m/s

System Characteristics Type of Separator

Large vapour, less liquid Load (by volume) Vertical

Large liquid, less vapour Load (by volume) Horizontal

Large vapour, large liquid Load (by volume) Horizontal

Liquid‐liquid separation Horizontal

Liquid‐solid separation Vertical

DISCUSSION

This spreadsheet provides an easy and simple approach to (2/3 phase and vertical/horizontal) separator sizing.

Formulae and references are also provided for process engineers to edit/duplicate this work (file is NOT

password protected).

Two sets of calculations are carried out here.

1. Separators with Mist Extractors and 2.

Separators without Mist Extractors

Selection guideline for separator types

There is as much art as there is science to properly design a separator. Three main factors should be

considered in separator sizing: 1)

vapor capacity, 2) Liquid capacity, and 3) operability. The

vapor capacity will determine the cross‐sectional area necessary for gravitational forces to remove the liquid

from the vapor. The liquid capacity is

typically set by determining the volume required to provide adequate residence time to “de‐gas” the liquid or

allow immiscible liquid phases to separate. Operability issues include the separator’s ability to deal

with solids if present, unsteady flow/liquid slugs, turndown, etc. Finally, the optimal design will usually result in

an aspect ratio that satisfies these requirements in a vessel of reasonable cost. These factors often result in an

iterative approach to the calculations.

Momentum & Velocity criteria for nozzles (Source: DEP 31.22.05.12 ‐ Gen.‐ 2008)

Several useful guidelines for separator design are provided below;


3/14

Level type Level setting

Level Alarm High High (LAHH) 30 – 60 seconds or 200 mm whichever is greater

Level Alarm High (LAH) 30 – 60 seconds or 200 mm whichever is greater

Normal Alarm Level (NAL) 60% of horizontal separator

Level Alarm Low (LAL) 30 – 60 seconds or 200 mm whichever is greater

Level Alarm Low Low (LALL)

30 – 60 seconds or 200 mm whichever is greater Should be

at least 200 mm above the vessel bottom or maximum

interface level

Separator type K factor (m/s)

Horizontal (with vertical pad) 0.122 to 0.152

Spherical 0.061 to 0.107

Vertical or horizontal (with horizontal pad) 0.055 to 0.107

At atmospheric pressure 0.107

At 2100 kPa 0.101

At 4100 kPa 0.091

At 6200 kPa 0.082At 10300 kPa 0.064

Wet steam 0.076

Most vapours under vacuum 0.061

Salt and caustic evaporators 0.046

Typical K factors for the sizing of wire mesh demisters (Source: IPS‐E‐PR‐880, 1997)

Level setting in the separator


4/14

INDEX

A total cross sectional area of the separator.

Aw cross sectional area of the separator occupied by water, ft2

Ao cross sectional area of the separator occupied by oil, ft2

Ag cross sectional area of the separator occupied by gas, ft2

CD drag coefficientd vessel internal diameter, in.

dm bubble or drop diameter, μm

D vessel diameter, ft

h liquid height, in.

hg gas‐phase space height, in.

ho oil pad height, in.

hw water pad height, in.

K mesh capacity factor, ft/sec

Leff or L effective length of the vessel where separation occurs, ft

Lss or Ls seam‐to‐seam vessel length, ft

NLL normal liquid level, %

P operating pressure, psia

Q c continuous liquid‐phase flow rate, bbl/day

Q g gas flow rate, MMSCFD or ft3/s

Q o oil flow rate, bbl/day

W or Q w water flow rate, bbl/day

Re Reynolds number

T operating temperature, °R

V liquid settling volume

Va max. allowable velocity through secondary separation section

Vm velocity of the mixture, m/s

Z gas compressibility

μc continuous phase dynamic viscosity, cp

μw water dynamic viscosity, cP

ρ density, lbm/ft3

ρg gas density, lbm/ft3

ρl liquid density, lbm/ft3

ρo oil density, lbm/ft3

ρm mean density of mixture, kg/m3

ρw water density, lbm/ft3

NOMENCLATURE


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INDEX

API 12J, Specification for oil and gas separators, 1989

Petroleum and Gas Field Processing ‐ Hussein K. Abdel‐Aal, Mohamed Aggour, M. A. Fahim

IPS‐E‐PR‐880, 1997

GPSA ‐ Engineering Data Book (12th Ed)

http://books.google.com.qa/books?id=lpA83iVcaGYC&pg=PA159&lpg=PA159&dq=Kh+%3D+1.25+Kv+separ

ator&source=bl&ots=fV8ewKHkag&sig=q70X8‐xfxPnk9MBMHgaEFwLhIhU&hl=en&sa=X&ei=M‐

REFERENCES

http://en.citizendium.org/wiki/Vapor‐liquid_separator

http://petrowiki.org/Separator_sizing

http://books.google.com.qa/books?id=BZOPlA‐

SmMUC&pg=PA97&lpg=PA97&dq=%22three+phase%22+separator+L/D+ratio+%22GPSA%22&source=bl&ot

http://en.wikipedia.org/wiki/Souders%E2%80%93Brown_equation

http://www.cheresources.com/invision/topic/11856‐selecting‐vertical‐separator‐ld‐ratio/

http://www.cheresources.com/invision/topic/17158‐three‐phase‐separator‐design‐suggestion‐needed/

http://en.citizendium.org/wiki/Vapor‐liquid_separator

http://www.chemicalforums.com/index.php?topic=8913.0

http://www.chemicalforums.com/index.php?topic=9252.0

http://www.cheresources.com/invision/topic/41‐sizing‐a‐flash‐tank‐or‐vapor‐liquid‐separator/

http://www.eng‐tips.com/faqs.cfm?fid=1153

http://process‐designs.com/

http://www.razifar.com/cariboost_files/Design_20Two_20Phase_20Separators_20Within_20the_20Right_2

0Limits.pdf


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STANDARD SEPARATOR SIZES AS PER API INDEX

D [in] x H or L [ft]

12¾ in x 5 ft

12¾ in x 7½ ft

12¾ in x 10 ft

16 in x 5 ft16 in x 7½ ft

16 in x 10 ft

20 in x 5 ft

20 in x 7½ ft

20 in x 10 ft

24 in x 5 ft

24 in x 7½ ft

24 in x 10 ft

30 in x 5 ft

30 in x 7½ ft

30 in x 10 ft

36 in x 5 ft

36 in x 7½ ft

36 in x 10 ft

36 in x 15 ft

42 in x 7½ ft42 in x 10 ft

42 in x 15 ft

48 in x 7½ ft

48 in x 10 ft

48 in x 15 ft

54 in x 7½ ft

54 in x 10 ft

54 in x 15 ft

60 in x 7½ ft

60 in x 10 ft

60 in x 15 ft


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INDEX

Q g 25 mmscfd

Q o 3000 bbl/d

γ 0.70

ρ'o 40 o

API

γo 0.83

P 814.5 psiaT' 80 oF

T 540 oR

MW 20.3 lb/lbmole Molecular weight

t 1 minutes

Z 0.84

µg 0.013 cP

H 10 ft

K 0.30 ft/s

NLL 30%

Step 1: Determine gas and oil properties

ρg 3.4 lb/ft3

ρo 51.5 lb/ft3 Height, ft Typical

K

factor

range

5 0.12 to 0.24

Step 2: 10 0.18 to 0.35

Va 1.13 ft/s

Q g,a 4.55 ft3/s

Ag,min 4.03 ft2 Oil Gravities

Retention time,

minutes (Typical)

Dmin 27 in Above 35 oAPI 1

20 to 30 oAPI 1 to 2

Dselected 30 in 10 to 20 oAPI 2 to 4

H 10 ft Shell height

H / D 4.0 unitless Refer Note 4

Step 3:

V 2.6 bbl

W 3777 bpd

2. Additional resource for K factor from GPSA Engineering Data Book:

K factor, m/s

0.11

0.11

0.10

0.09

0.08

0.07

GPSA Notes:

1. K = 0.107 at a gauge pressure of 7 bar. Subtract 0.003 for every 7 bar above a gauge pressure of 7 bar.

2. For glycol or amine solutions, multiply above K values by 0.6 ‐0.8.

3. Typically use one‐half of the above K values for approximate sizing of vertical separators without mesh pads.

4. For compressor suction scrubbers and expander inlet separators, multiply K by 0.7 ‐0.8.

3. Additional resource for retention times from gas Conditioning and Processing, Volume 2.

1 to 3 minutes

10 to 15 minutes

8 to 15 minutes

4 to 7 minutes

2 to 3 minutes4. As per GPSA, typical vertical H/D ratios are normally in the 2 to 4 range.

Fractionation feed surge tanks

Refrigerant surge tanks

Refrigerant econonomizers

7

21

42

63

105

Natural gas‐oil

Lean oil surge tanks

Pressure, barg

0

Oil operating density

Operating temperature


Retention time (Refer Table 2)

Gas compressibility

Shell height (assume)

Actual volume flow of gas

Minimum gas flow area

Liquid volume (excluding bottom head)

Liquid capacity of separator should be

more than 3000 bpd (input value)

Next larger and appropriate size

INPUT PARAMETERS

Gas rate

Gas specific gravity

Oil rate

Oil density

SCHEMATIC

Minimum ID of separator

Operating pressure

Table 2

Oil specific gravity

Refer Table 1

Normal liquid level (assume)

Adjustment of K factor for pressure

Two Phase (Gas ‐ Oil) Vertical separator: As per API 12J

Y e l l o w

b o x e s a r e i n p u t b o x e s .

NOTES

1. The maximum allowable superficial velocity calculated from the above factors is for separators normally having a wire mesh mist extractor.

This rate should allow all liquid droplets larger than 10 microns to settle out of gas.

TABLES

Table 1

CALCULATIONS

Gas operating density

EQUATIONS

Gas viscosity

300 85

600 80

1150 75

Pressure, psig % of Design value

Atm. 100

150 90


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INDEX

Q g 25 mmscfd

Q o 3000 bbl/d

γ 0.70

ρ'o 40 o

API

γo 0.83

P 814.5 psia

T' 80 oF

T 540 oR


t 1 minutes

Z 0.84

µg 0.012 cP

K 0.5 ft/s

NLL 30%

L 10 ft

EQUATIONS


ρg 3.4 lb/ft3

ρo 51.5 lb/ft3 Length, ft

Typical K factor

range, ft/s

10 0.4 to 0.5

Step 2: Other Lengths 0.4 to 0.5 x (L/10)0.56

Va 1.881 ft/s

Q g,a 4.55 ft3/s


Retention time,

minutes (Typical)

Dmin 4 in Above 35 oAPI 1

Ag,min 2.42 ft2


Error 0.00 10 to 20 oAPI 2 to 4

Dselected 30 in

L 10 ft

L / D 4.0 unitless

Step 3:

V 3 bbl

W 3644 bpd


K factor, m/s

0.11

0.11

0.10

0.09

0.08

0.07

GPSA Notes:


2. For glycol or amine solutions, multiply above K values by 0.6 ‐ 0.8.

3. For compressor suction scrubbers and expander inlet separators, multiply K by 0.7 ‐ 0.8.

3. Additional resource for retention times from gas Conditioning and Processing, Volume2.

1 to 3 minutes

10 to 15 minutes

8 to 15 minutes

4 to 7 minutes

2 to 3 minutes

4. As per GPSA, typical horizontal L/D ratios are normally in the 2.5 to 5 range.

Y e l l o w


NOTES

1. The maximum allowable superficial velocity calculated from the above factors is for separators normally having a wire mesh mist extractor. This

rate should allow all liquid droplets larger than 10 microns to settle out of gas.

Two Phase (Gas ‐ Oil) Horizontal Separator: As per API 12J

SCHEMATIC


Shell Length (assume)

CALCULATIONS TABLES

Refer Table 1

INPUT PARAMETERS

Gas rate


Oil rate


Assume

105

Natural gas‐oil




0

7

21

42

63




Pressure, barg

Gas operating density Table 1


Actual volume flow of gas Table 2


Next larger and appropriate size

Refer Note 4



Gas compressibility

Gas viscosity

Shell length

Oil density

Operating pressure





Atm. 100

150 90

300 85

600 80

1150 75


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INDEX

Q g 8 mmscfd

Q o 8000 bbl/d

Q w 3000 bbl/d

γ 0.70

ρ'o 40 o

API

γo 0.83

P 250 psia

T' 60 oF

T 520 oR


H 18 ft

to 5 minutes

tw 5 minutes

Z 0.84

µg 0.013 cP

K 0.35 ft/s

NLL 50%

EQUATIONS


ρg 1.1 lb/ft3

ρo 51.5 lb/ft3 Height, ft

Typical K factor range,

ft/s

5 0.12 to 0.24

Step 2: 10 0.18 to 0.35

Va 2.4 ft/s

Q g,a 4.58 ft3/s


Retention time,

minutes (Typical)

Dmin 19 in Above 35 oAPI 3 to 5

Dselected 96 in Below 35 oAPI

H 18 ft Shell height 100+ o

F 5 to 10

H / D 2.3 unitless Refer Note 4 80+ o

F 10 to 20

60+ oF 20 to 30

Step 3:

V 81 bbl

W 11602 bpd


K factor, m/s

0.11

0.11

0.100.09

0.08

0.07

GPSA Notes:


2. For glycol or amine solutions, multiply above K values by 0.6 ‐ 0.8

3. Typically use one‐half of the above K values for approximate sizing of vertical separators without mesh pads

4. For compressor suction scrubbers and expander inlet separators, multiply K by 0.7 ‐ 0.8


1 to 3 minutes

10 to 15 minutes

8 to 15 minutes

4 to 7 minutes

2 to 3 minutes

4. As per GPSA, typical horizontal H/D ratios are normally in the 2 to 4 range.

Water rate

Three Phase (Gas ‐ Oil ‐ Water) Horizontal Separator: As per API 12J


Y e l l o w


SCHEMATIC

INPUT PARAMETERS

Gas rate


Oil rate

Oil density

Operating pressure



Oil retention time (Refer Table 2)

Water retention time (Refer Table 2)

Gas compressibility

Gas viscosity

Refer Table 1


Shell height (assume)

CALCULATIONS TABLES



7

Next larger (than Dmin) and appropriate

size




Actual volume flow of gas



Pressure, barg

0

Table 2


Assume

NOTES





Atm. 100

150 90300 85

600 80

1150 75


2142

63

105

Natural gas‐oil



10/14

INDEX

Q g 8 mmscfd

Q o 8000 bbl/d

Q w 3000 bbl/d

γ 0.70

ρ'o 40 o

API

γo 0.83

P 250 psia

T' 60 o F

T 520 o R


L 18 ft

to 5 minutes

tw 5 minutes

Z 0.84

µg 0.013 cP

K 0.35 ft/s

NLL 50%

EQUATIONS


ρg 1.1 lb/ft3

ρo 51.5 lb/ft3 Length, ft

Typical K factor range,

ft/s

10 0.4 to 0.5

Step 2: Other Lengths 0.4 to 0.5 x (L/10)0.56

Va 2.388 ft/s

Q g,a 4.58 ft3/s


Retention time,

minutes (Typical)

Dmin 2.4 in Above 35 o

API 3 to 5

Ag,min 1.92 ft2

Below 35 o

API

Error 0.00 100+ oF 5 to 10

Dselected 78 in 80+ oF 10 to 20

L 18 ft 60+ oF 20 to 30

L / D 2.8 unitless

Step 3:

V 77 bbl

W 11036 bpd


K factor, m/s

0.11

0.110.10

0.09

0.08

0.07

GPSA Notes:


2. For glycol or amine solutions, multiply above K values by 0.6 ‐ 0.8

3. For compressor suction scrubbers and expander inlet separators, multiply K by 0.7 ‐ 0.8


1 to 3 minutes

10 to 15 minutes

8 to 15 minutes

4 to 7 minutes

2 to 3 minutes




Water rate

63

105

Natural gas‐oil




Pressure, barg

0

721

42




Three Phase (Gas ‐ Oil) Horizontal Separator: As per API 12J

NOTES



Actual volume flow of gas Table 2


Assume

TABLES

Operating pressure

CALCULATIONS




Gas compressibility

Gas viscosity

Y e l l o w

b o x e s a r e i n p u

t b o x e s .

SCHEMATIC


INPUT PARAMETERS

Gas rate


Oil rate

Oil density

Refer Table 1


Shell Length (assume)

Shell length

Next larger (than Dmin) and appropriate

size



Refer Note

4



600 80

1150 75

Atm. 100150 90

300 85


11/14

INDEX

Q g 15 mmscfd

Q o 3000 bbl/d

γ 0.6

ρ'o 35.0 o

APIγo 0.85

P 985 psia

T' 60 o

F

T 520 o

R

t 3 minutes

Z 0.84

µg 0.013 cP

dm 100 Micron


ρg 3.7 lb/ft3

ρo 53.0 lb/ft3

Step 2: Determine Cd

Cd 1.13 Assume

u 0.41 ft/s

Re 56

Cd 1.16

Error 0.00

Step 3: Check for gas capacity constraint

D2

974 in2

Dmin 31.2 in

Step 4: Check for liquid capacity constraint

D2H 77085

Try different combinations of D.

D, in H, in Ls, ft SR

30 85.7 13.5 5.4

36 59.5 11.3 3.8

42 43.7 10.5 3.0

48 33.5 10.1 2.5

54 26.4 10.0 2.2

60 21.4 10.1 2.0

66 17.7 10.3 1.9

72 14.9 10.6 1.8

78 12.7 10.9 1.784 10.9 11.2 1.6

90 9.5 11.6 1.6

Ls 11.3 ft

SR 3.8

D 36.0 in

Settling velocity of oil droplet

Reynolds no.

Use goal seek to get error zero, by changing

asssumed Cd

Minimum allowable vessel diameter for separation

of oil droplets down to 100 micron

Y e l l o w

b o x e s a r e i n p u t

b o x e s .

SCHEMATIC

Two Phase (Gas ‐ Oil) Vertical Separator: As per "Petroleum and Gas Field Processing ‐

Hussein K. Abdel‐Aal, Mohamed Aggour, M. A. Fahim"

EQUATIONS


Smallest oil droplet size to be removed

CALCULATIONS

Gas compressibility

Gas viscosity

INPUT PARAMETERS



Gas rate


Oil rate

Oil density

Operating pressure


Drag coefficient



1. As per GPSA, typical vertical H/D ratios are normally in the 2 to 4 range.

Slenderness ratio (typical value 3 to 4) (select from Table 1)

Seam to seam length (select from Table 1)

Separator diameter (select from Table 1)

1 to 2

2 to 4

20 to 30 oAPI

10 to 20

o

API

TABLE 1

TABLE 2 (Ref. API 12J)

Retention time,

1

NOTES

Oil Gravities

Above 35 o

API

Click me


12/14

INDEX

Q g 15 mmscfd

Q o 3000 bbl/d

γ 0.6

ρ'o 35.0 o

API

γo 0.85

P 985 psia

T' 60 o

F

T 520 o

R

t 3 minutes

Z 0.84

µg 0.013 cP

dm 100 Micron

NLL 50%


ρg 3.7 lb/ft3

ρo 53.0 lb/ft3


Cd 1.2 Assume

u 0.40 ft/s

Re 55Cd 1.19

Error 0.00


LD 83 in.ft


D2L 12852 in

2.ft


D, in Lg, ft

Ls, ft

(gas) Lo, ft Ls, ft (oil)

Governing

case

SR = 12

ls

(oil or

gas)/D

6 13.85 14.35 357.00 476.0

Liquid

Capacity 952.00

12 6.93 7.93 89.25 119.0

Liquid

Capacity 119.00

24 3.46 5.46 22.31 29.8

Liquid

Capacity 14.88

30 2.77 5.27 14.28 19.0

Liquid

Capacity 7.62

36 2.31 5.31 9.92 12.4

Liquid

Capacity 4.14

42 1.98 5.48 7.29 9.8

Liquid

Capacity 2.80

48 1.73 5.73 5.58 8.1Liquid Capacity 2.02

54 1.54 6.04 4.41 6.9

Liquid

Capacity 1.53

60 1.39 6.39 3.57 6.1 Gas capacity 1.28

66 1.26 6.76 2.95 5.5 Gas capacity 1.23

72 1.15 7.15 2.48 5.0 Gas capacity 1.19

Ls 12.4 ft

SR 4.1

D 36 in

Normal Liquid Level

INPUT PARAMETERS

Reynolds no.




Drag coefficient



CALCULATIONS


asssumed Cd

Gas compressibility

Gas viscosity

Gas rate


Oil rate

Oil density

Operating pressure


2. If D>30", Ls = 2.5 + Lo;

Else, Ls = (4/3)*Lo

Ref. http://process‐designs.com/separators_and_scrubbers/separators_and_scrubbers.jsp

Two Phase (Gas ‐ Oil) Horizontal Separator: As per "Petroleum and Gas Field Processing ‐


Seam to seam length (select from Table 1)

Slenderness ratio (typical value 3 to 5) (select from Table 1)


NOTES

SCHEMATIC


Y e l l o w

b o x e s a r e i n

p u t b o x e s .

EQUATIONS





Oil Gravities Retention time,

minutes (Typical)

TABLE 1

Above 35 oAPI 1


Click meClick me


13/14

INDEX

Q g 8 mmscfd

Q o 8000 bbl/d

Q w 3000 bbl/d Water rate

ρ'o 27.6 o

API

γo 0.89 Oil specific gravity

µo 20 cP Oil viscosity

γw 1.04

γ 0.65

Z 0.89

P 250 psia

T' 95 o

F

T 555 o

Rtw 10 minutes

to 15 minutes

µg 0.013 cP

dm,w 500 Micron

dm,o 100 Micron


ρg 0.89 lb/ft3

ρo 55.5 lb/ft3


Cd 2.07 Assume

u 0.65 ft/s

Re 22Cd 2.09

Error 0.00

Step 3:

D2

min 28428 in2

Dmin 168.6 in


D2

min 1475 in2

Dmin 38.4 in

Dmin 168.6 in


D2(Ho + Hw) 1286400 in

3


D, in Ho + Hw, in Ls, ft

SR = 12 Ls

/ D

16 5025 425.1 318.8

20 3216 274.3 164.6

24 2233 192.4 96.230 1429 125.4 50.2

36 993 89.0 29.7

42 729 67.6 19.3

48 558 53.9 13.5

54 441 44.6 9.9

60 357 38.1 7.6

120 89 20.8 2.1

132 74 20.5 1.9

Ls 20.8 ft

SR 2.1

D 120.0 in

Q g 86 mmscfd





CALCULATIONS


Drag coefficient


Smallest water droplet size to be removed

Determine minimum diameter for water droplet settling

Larger of Step 2 and 3 values

Reynolds no.

SCHEMATIC

Y e l l o w


EQUATIONS

Three Phase (Gas ‐ Oil ‐ Water) Vertical Separator: As per "Petroleum and Gas Field Processing ‐


INPUT PARAMETERS

Gas rate


Oil rate

Oil density


Gas compressibility

Gas viscosity


Operating pressure

Water specific gravity


Seam to seam length (select from table 1)

Slenderness ratio (typical value 1.5 to 3) (select from Table 1)


NOTES

1. As per GPSA, typical vertical H/D ratios are normally in the 2 to 4 range.

Calculated gas capacity for selected L & D (Should be more than 8 MMSCFD ‐ input value)

TABLE 1

100+

o

F80+

oF

60+ oF

Retention time, minutes

(Typical)

3 to 5

5 to 1010 to 20

20 to 30


Oil Gravities

Above 35 oAPI

Below 35 oAPI

Click me


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How to Size a Separator

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