separation technologyAn Technologies Subsidiary

l e a d i n g i n

SEPARATIONtechnology

TABLE OF CONTENTS

Introduction 1

Information Bulletins

SPIRAFLOWTM Cyclone 2

CDS-Gasunie Inlet CycloneTM 3

CDS-Gasunie Cyclone ScrubberTM 4

CDS-Statoil DegasserTM 5

Vane Pack 6

Miscellaneous Internals 7

R&D and Flow Visualisation 9

Computational Fluid Dynamics 10

Case Studies

SPIRAFLOWTM Demisting Cyclone 11

Vane Pack vs Cyclone 13

CDS-Gasunie Inlet CycloneTM (Liquid/liquid separation) 15

CDS-Gasunie Inlet CycloneTM (Defoaming) 16

CDS-Gasunie Cyclone ScrubberTM 17

CDS-Statoil DegasserTM 18

Contact Details 19

CDS Separation Technology in a nutshell

CDS designs and develops state-of-the-art separators.

Over the years, we have established a reputation for

supplying highly innovative separation solutions to the

offshore industry. A reputation that reflects our ability to

increase separator throughput, reduce extraction costs

and prolong the profitable exploration of depleted

oil fields.

Our objective is to make the oil extraction process more

efficient and less expensive. In pursuit of this objective,

we are able to draw on unparalleled expertise, advanced

in-house test facilities, the latest CFD tools and funda-

mental research. As you might expect, CDS has also

implemented a comprehensive quality management

system that complies with ISO 9001:2000 standards.

In September 2003 FMC Technologies acquired a

controlling interest in CDS.

As quality separation solutions are based on a thorough

understanding of your process parameters, we make

every effort to encourage and facilitate a close working

relationship with our customers. Moreover, as hundreds

of customers around the world will testify, we are

dedicated to providing you with a highly efficient and

cost-effective solution, no matter how diverse your

requirements may be.

This brochure describes our technology, research

capabilities and products. Should you require additional

information, please feel free to contact us. Our contact

details are found on the back of this brochure.

INTRODUCTIONpage one

SPIRAFLOWTM CYCLONEpage two

The CDS SPIRAFLOWTM cyclone provides a high separation efficiency of fine droplets and foam even at high operating

pressures. It can be positioned either vertically or horizontally within a vessel and due to its high capacity it is ideal for

the revamping of vessels. For new built applications the vessel size with these internals can be

substantially reduced leading to considerable vessel cost and weight savings. The SPIRAFLOWTM

cyclone is very efficient for low and high pressure applications and with low surface tension liquids.

Operating Principle

Mist enters the cyclone and flows through the stationary

swirl element causing an intense gas rotation. Droplets are

separated by the subsequent centrifugal action and are

coalesced into a

liquid film on the

cyclone inner wall.

This liquid film is purged out of the cyclone by a combination

of the rotating flow and the secondary gas flow.

The secondary gas flow is then recombined with the main

flow through a pipe leading to the centre of the cyclone.

Operating Characteristics

Separates all mist droplets > 5µm (Atmospheric conditions).

Vane/SPIRAFLOW 80 Efficiency Comparison

Atm. Cond. Gas 60 kg/m3 - Liquid 600 kg/m3

CDS 350 Vane CDS 250 Vane SPIRAFLOW cyclone

Dro

plet

Siz

e fo

r 10

0% s

epar

atio

n(m

icro

ns)

CDS-GASUNIE INLET CYCLONETM

page three

Operating Principle

The optimised blade geometry brings the combined phase

into rotation with minimum shear. The resulting centrifugal

force moves the liquid and solid particles towards the cyclone

wall, where they form a liquid film that flows to the bottom

of the cyclone. The gas leaves the cyclone through the central

vortex finder. The baffles in the bottom of the cyclone stop

the rotation of the liquid, and a blocking plate prevents

liquids from being entrained into the gas. In this way it is

ensured, that no gas carryunder or liquid carryover can occur.

Advantages

• Enables the debottlenecking of both liquid and gas

constrained vessels.

• Not susceptible to fouling.

• Excellent slug handling capabilities.

• High turndown.

The CDS-Gasunie Inlet CycloneTM can be used for the following services:

• Foam breaking. • Degassing.

• High liquid / liquid separation efficiency. • High inlet momentums.

Even at high inlet momentums (up to 65,000 kg/ms2) field trials have proved that both liquid / liquid separation and

defoaming capabilities are improved using this device making it ideal for

retrofit applications. For new built vessels both the size of the inlet piping

and vessel can be reduced thus providing an overall compact solution.

CDS-GASUNIE CYCLONE SCRUBBERTM

page four

The CDS-GasunieCyclone ScrubberTM can be used for separation

of liquids (water, hydrocarbon, glycol, etc.) from gases (natural

gas and other), for the protection of downstream equipment

(compressors, gas turbines, flow meters, etc.). Solid particles

(dust, sand, etc.) will also be removed, making the scrubber

suitable for use as a gas wellhead separator.

Operating Principle

The optimised blade geometry brings the combined phase

into rotation. The resulting centrifugal force moves the liquid

and solid particles towards the vessel wall, where they form

a liquid film that flows to the bottom of the vessel.

The gas leaves the vessel through the central vortex finder

connected to the gas outlet nozzle. The baffles in the bottom

of the vessel stop the rotation of the liquid, and a blocking

plate prevents liquids from being entrained into the gas.

In this way it is ensured, that no gas carryunder or liquid

carryover can occur.

Advantages

• Results in small size and low weight as a result of high

allowable gas load factor. It is therefore especially

attractive for offshore applications.

• Maintenance friendly: No small channels or downcomer

pipes that are prone to fouling.

• Excellent slug handling capabilities.

• High turndown.

• Available as retrofit package.

• Over 200 references in a wide variety of applications.

Demister Gas Capacity Comparison

Gas

Loa

d Fa

ctor

(m

/s)

Gas 60 kg/m3 - Liquid 600 kg/m3

Mesh CDS 350 CDS 250 SPIRAFLOW CDS-GasunieVane Vane Cyclone Cyclone

CDS-STATOIL DEGASSERTM

page five

The CDS-Statoil DegasserTM is an inline device that separates

gas from liquid. It has no moving parts and requires no power.

Due to a very effective but simple control system it has a very

high separation efficiency regardless of flow fluctuations.

The separation efficiency is above 99.5% of gas from liquid,

while the separated gas is 100% free of liquid.

The diameter of the Degasser is generally the same as the line

into which it will be installed. Due to this and the fact that it

can be certified as a piece of pipe as opposed to a pressure

vessel the installation cost is low and maintenance is minimal.

In the Degasser gas and liquid are separated when the

multiphase fluid enters the separator where a stationary

swirl element causes the flow to rotate. This rotation forces

the liquid to flow along the outer wall and the gas to flow

in the centre. The gas is removed from the centre into a

scrubber section along with a portion of the liquid for control

purposes. This ‘control’ liquid subsequently rejoins the main

liquid flow leaving the Degasser after the main flow has

passed through an antiswirl element, intended to provide

pressure recovery and to prevent downstream vibrations.

Applications:

• Increases the capacity of existing separators by taking

out the gas upstream of them.

• Reduces the size of new separator vessels.

• Debottlenecking of multiphase lines.

• Debottlenecking of gas limited facilities.

Advantages:

• In-line.

• No (big) vessels necessary.

• Low installation costs.

• Minimal maintenance costs.

• Very flexible to flow fluctuations.

• Separation of gas from liquid > 99.5%.

• Separated gas is 100% free of liquid.

• The gas can go straight to compression or

to flare without further processing.

An 18-inch degasser for a produced water line.Capacity water 60,000 Sm3/d; gas 98,000 Sm3/d

An 11-inch test degasser.Capacity water 9,600 Sm3/d; gas 15,700 Sm3/d

VANE PACK page six

CDS offers a complete range of efficient vane packs including

the single and double pocket 200 series vanes for horizontal

flow and 300 series vanes for vertical flow.

Operating Principle

The mist laden gas passes through the parallel vane plates

and is forced to change direction several times. The mist

droplets are separated by the subsequent centrifugal forces

and are collected on the vane blades. This coalesced liquid

film is then removed through slits or pockets into a liquid

sump and drained to the liquid compartment of the vessel.

Operating Characteristics

Separates all mist droplets > 8µm (Atmospheric conditions).

Maximum pressure drop = 9 mbar.

CDS 350 CDS 250

CDS 230

Demister Gas Capacity Comparison

Gas

Loa

d Fa

ctor

(m

/s)

Gas 60 kg/m3 - Liquid 600 kg/m3

Mesh CDS 350 CDS 250 SPIRAFLOW CDS-GasunieVane Vane Cyclone Cyclone

MISCELLANEOUS INTERNALSpage seven

Perforated Distribution Baffle

In order to achieve an efficient gas / liquid and liquid / liquid

separation in horizontal vessels it is important to have a

quiescent flow regime along the length of the vessel.

This is accomplished by use of perforated baffles that have

shown both in tests, CFD models and more importantly

in the field that without these internals the separation

process can be adversely affected. The baffles can be

installed singularly, in a double arrangement and both full

and part diameter depending upon the intended duty.

Mesh Type Agglomerator

If a very high degree of gas / liquid separation is required or

if the separation duty is arduous either due to the presence of

small droplets or a high liquid load then use can be made of

mesh type agglomerators. They can be used both in horizontal

and vertical orientations and are intended to capture and

agglomerate the droplets and to seperate some of the liquid

prior to it entering the final mist eliminating device. Internal

drainage channels in the mesh ensure the efficient removal of

this separated liquid.

Sand Jetting System

Where sand or solid deposition in vertical or horizontal

vessels is expected, jetting systems can be installed.

Sand jetting systems fluidise the solids by use of pressurised

water introduced through spray nozzles for draining through

sand drains located down the length of the vessel.

The system can be arranged to flush the complete

length of the vessel at the same time or if the supply

is limited the system can be sectioned for the

flushing of smaller lengths.

MISCELLANEOUS INTERNALSpage eight

The EVENFLOW TYPE HE

The EVENFLOW TYPE HE inlet device is used to decrease the

momentum of the incoming feed stream, allowing removal of

any bulk liquids and solids that may be present and to evenly

distribute the gas flow over the vessel cross section. The even

distribution is necessary in order to minimise any chance of

channelling occurring through downstream devices and to

maximise gravity separation. Since it does not direct the fluids

downwards directly onto the liquid surface, re-entrainment

effects are minimised.

DEMISTER® Mist Eliminator

CDS can supply the complete range of standard and

traditional wire mesh mist eliminators. Through our

alliance partner Koch-Otto York we can offer reliable

quality and short delivery times

Plate Pack Coalescer

Plate pack coalescers are used in the liquid section of a

separator in order to maximise the amount of liquid / liquid

separation. The operating principle of plate packs relies on

the fact that the flow through the narrowly spaced plates

will be laminar and since the distance the dispersed phases

have to travel to the interface is much smaller, smaller

droplets will be separated.

R&D AND FLOW VISUALISATIONpage nine

CDS continually strives to develop new separation devices

and techniques for general and/or specific uses. In this way

we lead the market in the development and use of innovative

technology. Additionally we can verify and test internals,

either part or fullscale, to ensure that they will be sufficient

for their intended service.

In order to accomplish this we extensively make use of the

following methods:

• Computational Fluid Dynamics.

• Atmospheric test rigs using air and a multitude of liquids.

Maximum flow rates are 2,000 Nm3/hr of air and

100 m3/hr of liquid.

• High-pressure test rig using natural gas to a pressure of

40 barg and a multitude of liquids.

• "See through" high-pressure test rig (3-phases) with the

following characteristics:

- Gas: 4,000 am3/hr up to 60 kg/m3.

- Liquid: 800 m3/hr (2-phases).

• Equipment to perform flow visualisations.

• Comprehensive literature searches and theoretical analysis.

We also actively participate in joint industry projects and

partnerships. Examples of operators and universities with

which we participate are: Statoil, NAM, Shell, Norsk Hydro,

Technical University of Delft, Eindhoven University of

Technology.

Major projects to date include:

• Development of a vertical 3-phase separator concept

used on the Tune development for Norsk Hydro.

• Development of a novel liquid/liquid cyclone for both

water-oil cleanup and bulk separation.

• Development of a novel inline degassing cyclone leading

to a substantial reduction in gas loading of downstream

equipment.

• Deliquidiser for inline separation of bulk liquids

from the gas stream.

• Separation-turbine that can be used as a

replacement of the Joule-Thomson valve.

COMPUTATIONAL FLUID DYNAMICSpage ten

Flow distribution is critical in all gas / liquid and liquid /

liquid separation processes. As vessel sizes are reduced, or

more capacity is required from existing equipment, traditional

rules for the layout of vessel internals must be reviewed.

Flow velocities through inlet nozzles, outlet nozzles, internals

and over liquid levels can affect the separation performance.

A tool used by CDS to investigate this is Computational Fluid

Dynamics, which provides an accurate representation of the

flow profiles inside a separator.

CFD can also be used to model time dependent applications

like floating separators to ensure that the proposed slosh

mitigation technique is adequate for both 2- and 3-phase

separators. Two examples of this are shown below.

CFD is not only limited to individual vessels but can also

be used to evaluate flows in piping systems, or flow

distributions in manifolds as shown below.

CFD can be used for steady state cases,

for instance when looking at the flow profile through a

scrubber vessel as shown above.

SPIRAFLOWTM DEMISTING CYCLONEpage eleven

In recent years CDS Engineering has performed a series of

upgrades of the Feed Gas Scrubber and 2nd Stage

Recompressor Scrubber upstream of the Amine Absorbers

on a North Sea production platform.

Process Scheme

As shown in the figure, the gas streams from both scrubbers

are combined together prior to entering the Amine Absorbers

for CO2 removal.

The thought behind the design was that in order to avoid

liquid entering the absorbers, due to condensation in the

piping and carryover, the gas from the Feed Gas Scrubber

would be mixed with the relatively hot gas from the 2nd Stage

Compressor resulting in superheated gas entering the

absorbers. However, due to substantial liquid carryover from

the scrubbers, a superheated state of the gas was not

achieved. This meant that liquid entered the absorbers,

resulting in poor CO2 removal performance and operational

difficulties.

To tackle this problem the 2nd Stage Recompressor Scrubber

went through a series of retrofits in order to reduce liquid

carryover.

1) Feed Gas Scrubber

2) Amine Absorbers

3) 2nd Stage Recompressor Scrubber

4) 2nd Stage Compressor

1 2

2

3

4

4

▼

▼

▼

▼

▼

▼

▼

SPIRAFLOWTM DEMISTING CYCLONEpage twelve

In order to determine the effectiveness of the retrofits a

comparative C6+ analysis was used. This involved taking a

sample of gas before it entered the absorbers. This gas was

then analysed and the amount of C6+ components was

recorded. As more liquid entered the absorbers the C6+

value increased.

The original internals in the vessel comprised a type of half

open pipe inlet device and a vane pack. Due to shutdown

time limitations, initially only the inlet device was replaced

by a vane type inlet device, which reduced the C6+ by 20%.

The following year the vane pack was replaced with

AXIFLOWTM cyclones, the forerunner of the SPIRAFLOWTM

cyclone, which showed a 44% reduction in C6+.

The problem with the operation of the Amine Absorber as

described above was finally tackled in 1999 by replacing

the AXIFLOWTM cyclones with SPIRAFLOWTM cyclones.

The installation of the SPIRAFLOWTM cyclones resulted in

a substantial improvement in performance of the vessel

with a 68% reduction in C6+. The table below shows a

summary of these retrofits.

2nd Stage Recompression ScrubberOperating Pressure: 44.7 bara

Year Retrofit Summary Internals C6+ Performance

(%) Improvement

1996 Old Configuration Cowcatcher Inlet + Vane Pack 0.8 to 2.0 Base

1997 Quick Fix Vane Inlet + Vane Pack 0.7 to 1.6 13 to 20 %

1998 AXIFLOWTM Upgrade Vane Inlet + AXIFLOWTM Cyclones 0.4 to 0.9 43 to 44 %

1999 SPIRAFLOWTM Upgrade Vane Inlet + SPIRAFLOWTM Cyclones 0.13 to 0.3 67 to 68 %

VANE PACK VS CYCLONEpage thirteen

Referring to the SPIRAFLOWTM Case Study, it is seen that

after the 1998 retrofit, when the vane pack was replaced

by cyclones, there was less liquid carryover from the vessel

(44% decrease in C6+). This substantial reduction in carryover

with cyclones is explained by two mechanisms:

1) Droplet removal characteristics

For both cyclones and vane packs, droplets are removed as a

result of a change in direction of the gas flow. With this

change in direction, the droplets are subjected to forces,

moving them towards a surface onto which they coalesce,

thus establishing separation. In a cyclone a highly swirling gas

flow is generated through a static swirl element whereas in a

vane pack the flow of the gas only changes direction due to

the bends in the corrugated parallel plates. Due to the

mechanism of swirl generation, higher acceleration forces are

established in a cyclone. This means it is far more efficient

than a vane pack at removing droplets. This becomes more

apparent at increased operating pressures where separation

becomes difficult due to the decreased density difference

between the gas and the liquid and re-entrainment effects,

which are discussed later. CDS Engineering has performed

extensive tests at a pressure of 40 bar, which show that vane

packs fail to separate the small droplets that cyclones

efficiently remove. It should be noted that at lower than

design gas throughputs, the droplet removal capabilities of

vane packs drop substantially faster than with cyclones.

2) Re-entrainment of liquids

For both vane packs and cyclones the limiting factor in

terms of maximum capacity of the unit is the occurrence

of liquid film re-entrainment. This sets the allowable gas

throughputs and therefore limits the velocity and hence

accelerations within the body of the unit.

VANE PACK VS CYCLONEpage fourteen

Ultimately this will therefore limit the droplet size that can be

removed by the device. After all it is pointless to separate

something that is going to re-entrain and be carried-over.

The re-entrainment mechanism in vane packs essentially

occurs at the end or tip of the corrugated plates. Here,

separated liquid that runs along the plate gets torn off due to

the shear forces exerted by the gas onto the liquid. For the

maximum shear force, which is determined by liquid

properties, the gas velocity has to decrease for high gas

densities. This is because shear force is proportional to ρv2.

One of the liquid properties that limits the allowable shear

stress in a vane is the surface tension. As the surface tension

reduces, the allowable shear stress also drops. This is why

separation problems are generally seen with vane packs at

higher operating pressures when gas densities are high and

liquid surface tensions are low.

Within axial flow cyclones, this effect is suppressed because

of the centrifugal stabilisation caused by the swirling flow of

the gas, keeping the liquid film in contact with the cyclone

wall. In this way cyclones can process far more gas than vane

packs before re-entrainment occurs and therefore still separate

the smaller droplets.

For the SPIRAFLOWTM cyclone, the re-entrainment

mechanism is different to that of vanes since the liquid is

contained inside the cyclone tube as a continuous spinning

film, i.e. there is no end or tip at the outlet from which liquid

gets torn off. A pressure force acting on the liquid discharge

slots in the cyclones causes re-entrainment. In operation this

pressure force is opposed by the centrifugal force generated

by the spinning liquid. For each application it is ensured that

the centrifugal force is greater than the pressure force so that

no re-entrainment occurs. Since the centrifugal forces in the

cyclone are higher than in a vane more gas can be processed

before re-entrainment becomes a problem.

A further benefit is that the re-entrainment mechanism of

the SPIRAFLOWTM cyclone is not affected by surface tension.

The figure above shows the maximum velocity for a vane

pack (v max) that is dictated by the re-entrainment ρv2 limit.

The other lines show the minimum velocities required within

the vane in order to remove 20, 35 and 70 micron droplets.

As can be seen 20 micron droplets cannot be removed at gas

densities greater than around 10 kg/m2 since the required gas

velocity would exceed the re-entrainment limit.

The figure above shows the maximum throughput for a

cyclone (Q max) that is dictated by the re-entrainment limit.

The other lines show the minimum throughputs required

within the cyclone in order to remove 12, 15 and 20 micron

droplets. As can be seen all droplets can be removed, even

at the higher gas densities, without exceeding the re-

entrainment limit.

v (m

/s)

Gas Density (kg/m3)

Thro

ughp

ut/C

yclo

ne (

m3 /

h)

Gas Density (kg/m3)

Q

Q

Q

Q

page fifteen

Liquid / Liquid Separation

On Statfjord C, a Statoil operated platform

in the North Sea, a CDS-Gasunie Inlet

CycloneTM was tested in the Test

Separator. The purpose of this test was to

evaluate the liquid / liquid separation

performance in order to check the

feasibility of revamping the main

production separator on the platform.

In order to evaluate the liquid / liquid separation performance

the Test Separator was modified to provide 17 extraction

points for liquid samples at various distances from the

cyclone and at various heights.

The actual test conditions were very challenging especially

considering possible phase inversion due to the water cut

range of 42% to 76% and droplet shearing within the inlet

piping due to the high momentum values of up to

65,000 kg/ms2.

It was found that the inlet cyclone arrangement operated

very well with an oil in water quality that in the majority of

cases was below 40 mg/l meaning that it could be disposed

of to sea without further treatment. In all cases the water in

oil quality was below 5%. These results were maintained up

to an inlet momentum of 65,000 kg/ms2 whereas the normal

separator inlet nozzle design criteria is between 6,000 kg/ms2

and 10,000 kg/ms2. The complete set of results are shown

above together with the water in oil results that

were achieved with a simple deflector plate

inlet device.

% Water in oil inlet cyclone

% Water in oil deflector plate

Oil in water (ppm) inlet cyclone

Water cut (%)

Field Test at Statfjord CJanuary 1999

Inlet Momentum (kg/ms )

% W

ater

in o

il

2

Oil

in w

ater

(pp

m)

Wat

er c

ut (

%)

CDS-GASUNIE INLET CYCLONETM

Defoaming

High injection rates of defoaming chemicals

had been required to operate the production

and test separators on the Mars TLP, a Shell

operated platform in the Gulf of Mexico.

In an effort to reduce the chemical

consumption, different means of

mechanically breaking the foam were

investigated in the Test Separator including

AXIFLOWTM demisting cyclones and a

CDS-Gasunie Inlet CycloneTM. The result was

that for two different wells, the chemical

consumption was reduced by 20% and 80% respectively.

On the basis of the successful test results with the Test

Separator, the four main production separators were

retrofitted with new internals. Chemical consumption has

been reduced in the order of 50%. Other operational

problems due to foaming listed below were also reduced:

• Poor level control that led to platform shutdowns.

• Liquid carryover in the gas outlet that led to flooding

of downstream scrubbers and compressors.

• Gas carryunder in the liquid outlet that led to increased

downstream compression requirements.

The figure above indicates increasing total production rates

(red line) while reducing the defoamer consumption

(blue line). The CDS internals were installed in June 1998.

Chemical Scorecard Defoamer5 Month Rolling Average

Oil,

MB

bl

Gal

/MB

blCDS-GASUNIE INLET CYCLONETM

page sixteen

production rate

defoamer consumption

CDS-GASUNIE CYCLONE SCRUBBERTM

page seventeen

In a development project performed by CDS Engineering in

association with Gasunie Research, the conventional Gasunie

type cyclone scrubber was analysed and points for improvement

were identified. With the use of CFD and high-pressure tests

at the Gasunie Research facility, several geometrical

improvements regarding the fluid flow inside the separator

were tested. It was found that by optimising the separator

internals, the pressure drop could be reduced by 50%.

During further high-pressure tests it was verified that the

separation efficiency remained the same.

The benefit of the optimised design is that when designing

for the same pressure drop and separation efficiency, the

separator vessel can be reduced in size, leading to savings

on capital investment cost.

A case study was carried out for a gas-liquid separation

section of a gas production plant. The gas comes straight

from the wellhead and enters a CDS-Gasunie type separator.

Liquids (hydrocarbon and water), as well as sand, are

separated from the gas. After cooling, the gas runs through a

second CDS-Gasunie type separator, before entering a

compression module and the downstream gas treating plant.

Taking the conventional Gasunie cyclone as a base case, the

vessel ID and Tan/Tan length could both be reduced to 84%

for the new CDS-Gasunie design. This led to a lower

investment cost for the combined pressure vessel and

internal.

Results of case study

Conventional Design Optimised Design

ID 835 mm 700 mm

Tan/Tan 4,100 mm 3,438 mm

Relative Cost 1.00 0.85

CDS-STATOIL DEGASSERTM

page eighteen

Produced water from an inlet separator, test separator and

flash drum of a platform in the North Sea contains dissolved

hydrocarbon gas. The water is being cleaned of oil through

a set of hydrocyclones prior to pressure let down and

discharge to sea via the produced water-degassing drum.

Due to the pressure drop through the hydrocyclones, piping

and level control valves, gas will evolve from the produced

water. As a result of a combination of unfavourable pipe

routing together with an unacceptable ratio between gas and

water, the fluid flow in the 18" pipe from the hydrocyclones

to the produced water-degassing drum is in the slug flow

regime. These slugs result in strong vibrations in the piping

leading to the produced water flash drum in addition to

creating surge conditions in the flare system. This problem

puts a limitation to the capacity of the system as well as being

a safety concern due to the vibrations.

The goals for the installation of an 18-inch degasser were:

• Stop vibrations in the piping system to remove the risk of

mechanical fatigue and increase the capacity of the

system.

• Avoid pulsations and instability in the gas flow system.

• Reroute the separated gas to the recompression system

instead of flaring it as before. This is good for the

environment as well as giving a huge saving in CO2 taxes.

Design Data of the 18" Degasser

Operating Pressure (barg) 3-6

Operating Temperature (°C) 84

Max Water Flowrate (Sm3/d) 60,000

Max Gas Flowrate (Sm3/d) 98,000

Gas Fraction (%) 20 – 45

NOTESpage nineteen

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separation technologyAn Technologies Subsidiary

NOTESpage twenty

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separation technologyAn Technologies Subsidiary

FPSO: STATOIL ÅSGARD A

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