separation technology An
Technologies Subsidiary
leading
in
SEPARATION
technology
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
INTRODUCTION page one 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 fundamental 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.
SPIRAFLOWTM CYCLONE page 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).
Droplet Size for 100% separation (microns)
Vane/SPIRAFLOW 80 Efficiency Comparison
CDS 250 Vane
CDS 350 Vane Atm. Cond.
Gas 60 kg/m3 - Liquid 600 kg/m3
SPIRAFLOW cyclone
CDS-GASUNIE INLET CYCLONETM page three 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.
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.
CDS-GASUNIE CYCLONE SCRUBBERTM page four The CDS-Gasunie Cyclone 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.
Gas Load Factor (m/s)
Demister Gas Capacity Comparison
Mesh
CDS 350 Vane
CDS 250 Vane
SPIRAFLOW Cyclone
Gas 60 kg/m3 - Liquid 600 kg/m3
CDS-Gasunie 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.
An 18-inch degasser for a produced water line. Capacity water 60,000 Sm3/d; gas 98,000 Sm3/d
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.
An 11-inch test degasser. Capacity water 9,600 Sm3/d; gas 15,700 Sm3/d
•
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.
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.
CDS 350
CDS 250
CDS 230 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.
Gas Load Factor (m/s)
Demister Gas Capacity Comparison
Mesh
CDS 350 Vane
CDS 250 Vane
SPIRAFLOW Cyclone
Gas 60 kg/m3 - Liquid 600 kg/m3
CDS-Gasunie Cyclone
MISCELLANEOUS INTERNALS page 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 INTERNALS page 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 VISUALISATION page 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
•
Development of a novel liquid/liquid cyclone for both
used on the Tune development for Norsk Hydro. 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 DYNAMICS page 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 CYCLONE page 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
▼ 1
on a North Sea production platform. 2 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.
2
▼
4
▼ ▼
4
3 1) Feed Gas Scrubber 2) Amine Absorbers 3) 2nd Stage Recompressor Scrubber 4) 2nd Stage Compressor
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.
SPIRAFLOWTM DEMISTING CYCLONE page 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 Scrubber Operating 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 CYCLONE page 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 CYCLONE page 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.
v (m/s)
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 Gas Density (kg/m3)
densities. This is because shear force is proportional to ρv2. One of the liquid properties that limits the allowable shear
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
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.
velocity would exceed the re-entrainment limit. 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
Throughput/Cyclone (m3/h)
the smaller droplets.
Q
For the SPIRAFLOWTM cyclone, the re-entrainment
Q
mechanism is different to that of vanes since the liquid is
Q Q
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
Gas Density (kg/m3)
the centrifugal force is greater than the pressure force so that no re-entrainment occurs. Since the centrifugal forces in the
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 reentrainment limit.
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.
CDS-GASUNIE INLET CYCLONETM page fifteen Liquid / Liquid Separation
Field Test at Statfjord C January 1999
On Statfjord C, a Statoil operated platform
% Water in oil
Oil in water (ppm) Water cut (%)
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.
Inlet Momentum (kg/ms2) In order to evaluate the liquid / liquid separation performance % Water in oil inlet cyclone the Test Separator was modified to provide 17 extraction % Water in oil deflector plate points for liquid samples at various distances from the Oil in water (ppm) inlet cyclone cyclone and at various heights. Water cut (%) 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.
CDS-GASUNIE INLET CYCLONETM page sixteen Defoaming
Chemical Scorecard Defoamer 5 Month Rolling Average
High injection rates of defoaming chemicals had been required to operate the production
Gal/MBbl
Oil, MBbl
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 production rate defoamer consumption
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.
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
3
Max Gas Flowrate (Sm /d)
98,000
Gas Fraction (%)
20 – 45
NOTES page nineteen ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. ............................................................. .............................................................
separation technology An
Technologies Subsidiary
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separation technology An
Technologies Subsidiary
FPSO: STATOIL ÅSGARD A
CONTACT DETAILS
Head Office: CDS Engineering bv Delta 101 6825 MN Arnhem, The Netherlands Tel. 00 31 26 7999100 Fax. 00 31 26 7999119 e-mail:
[email protected] www.cdsengineering.com
Sales Offices: CDS Separation Technologies 1500 South Dairy Ashford Suite 441 Houston TX 77077, USA Tel. 00 1 281 529 8470 Fax 00 1 281 529 8471 e-mail:
[email protected] www.cdsengineering.com CDS Norge AS Hamang Terrasse 55 1336 Sandvika, Norway Tel. 0047 67522530 Fax. 0047 67522531 e-mail:
[email protected] www.cdsengineering.com CDS Engineering Asia Pacific Level 29 The Forrest Centre 221 St. Georges Terrace Perth WA 6000, Australia Tel: 00 61 894 803 701 Fax: 00 61 894 813 177 e-mail:
[email protected] www.cdsengineering.com CDS Brazil FMC CBV Subsea Rod. Pres. Dutra, 2660 km 2,5 Pavuna Rio de Janeiro/RJ Brasil CEP 21538 900 Tel. 00 5521 2472 7770 Fax. 00 5521 2471 2924 e-mail:
[email protected] www.cdsengineering.com
separation technology An
Technologies Subsidiary
DEMISTER® is a registered trademark. SPIRAFLOWTM, AXIFLOWTM, CDS-Gasunie and CDS-Statoil products are trademarks of CDS Engineering.
