LysarkForde2010

part of Aker

© 2008 Aker Solutions

Drying of natural gasThomas Førde, October 21, 2010

Troll A

Slide 2 © 2008 Aker Solutions part of Aker

Layout

1. Introduction/motivation2. Industrial examples 3. Theory drying

• Dehydration

4. Summary


BackgroundExplanations

■ Raw natural gas; gas produced from the well

■ Sour natural gas; contains hydrogen sulfide H2S or carbon dioxide CO2

■ Sweet natural gas; contains little sulfur and carbon dioxide

■ Rich natural gas; contains larger quantities of higher hydrocarbons

■ Wet natural gas; is saturated with water vapor under natural conditions

Petroleum technology volume 1-2 chapter 13 natural gas

Introduction

Kårstø Statoilhydro photo


IntroductionGas specifications

Gas and liquid contracts usually contain the following basic considerations:■ Gas

1. Minimum, maximum and nominal delivery pressure2. Maximum water content (expressed as a dewpoint at a given pressure or

concentration)3. Maximum condensable hydrocarbon content (expressed as a

hydrocarbon dewpoint )4. Allowable concentration of contaminants (H2S, carbon disulfide…)5. Minimum and maximum heating value6. Cleanliness (allowable solids concentration)

■ Liquid1. Quality of product (expressed as vapor pressure, relative or absolute

density)2. Specification (color, concentration of contaminants)3. Maximum water content

Introduction


MotivationTreating

■ Water must be removed● Solid hydrates with hydrocarbons or hydrogen sulfide

● Slugs in pipeline

● Corrosive H2S and CO2

Petroleum technology volume 1-2 chapter 13 natural gas, Natural gas production processing transport A.Rojey et.al

Introduction

■ Hydrogen sulfide (H2S) must be removed ● Toxic and corrosive

● Often done centralized treatment plants

■ Nitrogen● No heating value


MotivationFlow configurations

Principal sketch natural gas, well to consumer

• Well-stream from sub-sea/platform to shore (LNG; Snøhvit, gas export; Troll and Ormen Lange)

• Platform with full gas processing gas export (Sleipner)

Sleipner

snøhvit

Troll, ormen lange

Troll

Introduction

Off shore platform processing

Pipe line

Pipe line to europe

LNG

1: Off shore to land, pipe line demands

2: Export pipe line, demands

3: LNG composition demands

Refinery and petrochemicals

4: Condensate composition demands


MotivationTypical north sea natural gas composition

Major components (mol percentage dry gas) in some north sea gas reservoirs

It can be seen from the table, that Troll produced very lean gas.

Other fields contains more CO2 and heavy components.

Introduction

1 Petroleum technology chapter 13 * hydrocarbons

A Well stream, B Pipeline stream

Saturated

Saturated

Saturated

Saturated

Saturated

H20

1-10

3

0.15

4.13

1.51

Propane

0-1

0.38

7.9

12.4

0.31

Other*

0-5

-

He

0-3

0.49

-

H2S

8.6833.421.6SleipnerB

0.4724.865.80.38South-east asian field

8.7071.083.360.32KristinA

1-15

3.53

EthaneMethaneCO2N2

75-99

92.69

0-300-15Typical [1]

0.221.74TrollAA


Industrial examples


Natural gas processing

Principal sketch natural gas processing route

Industrial


Industrial examplesTroll, Kolsnes onshore plant

Industrial

Simplified flow sheet Troll onshore gas treatment plant Kolsnes


Industrial examplesPrincipal sketch Troll, MEG* System

Industrial

Background:

•Troll is located in the north part of the North Sea, about 65 km west of Kolsnes

• Ocean depth is above 300 meter

• The field is divided into Troll east and Troll west

• 2/3 of the recoverable gas reserve is located in the east* Monoethylene Glycol (MEG) also called ethylene glycol (EG)


Troll Dehydration system

Feed gas from slug catchers

Inlet gas separator

(Pressure, BARG)<Temperature, Celcius>

(90)<5>

(89.5)<-5.1>

(67)<-21>

(69.4)<-20.2>

Condensate and Glycol

(69)<-20.2>

(68.5)<-11.7>

(78.4) <-0.7>

Lean gas to pipeline compressorsTurboexpander

Suction drum

Dewpoint separator

MEG


Principal sketch KristinAll processing offshore

Kristin is a high pressure field (900 in the well, choke sea bottom to 350 bar)

Ocean depth is about 350 meters

Gas is transported to Kårstø

Economic choice of technology; takes advantage of high well pressure and existing single phase pipe-line to Kårstø

Full processing offshore to meet existing pipe-line spec (105 cricondenbar) inlet pipeline pressure 211 bar and 50 degrees Celsius

Gas is delivered at Kårstø at 100 bar

Industrial

Q Q


KristinLiquid separation system

Sketch of Kristin’s liquid separation system

Inlet separator

2nd stageseparator

3rd stageseparator

1st stage recompressor



To Dehydration system

<Temperature, Celcius>(Pressure, BarA)

<112>(87)

<120>(26)

<74>(2.15)

<30>(1.7)

<30>(7)

<26>(25)

To condensate storage

Inlet wet gas

pressure reduction

Pressure increasing


KristinSeparation re-compressor package

From separator

To separator

Out of recompressorCompressor separator

Sketch of Kristin’s separator recompression system


Principal sketch KristinAll processing offshore

Kristin is a high pressure field (900 in the well, choke sea bottom to 350 bar)

Ocean depth is about 350 meters

Gas is transported to Kårstø

Economic choice of technology; takes advantage of high well pressure and existing single phase pipe-line to Kårstø

Full processing offshore to meet existing pipe-line spec (105 cricondenbar) inlet pipeline pressure 211 bar and 50 degrees Celsius

Gas is delivered at Kårstø at 100 bar

Industrial

Q Q


KristinDe-hydration (TEG) system

Sketch of Kristin’s dehydration system

TEG: Triethylene glycol


SnøhvitPrincipal sketch

Industrial

Slug catcher

Inlet separation

MEGRecovery

Condensate treatment

Feed from pipeline CO2

Removal

CO2

De-hydration

Mercury Removal

Natural gas liquefaction

To pipeline LNG

storage

LPGstorage

Condensate storage Fractionation

First developed field in the Barents sea

Ocean depth of 300-350 meters

A gas field with condensate and an underlying thin oil zone

Choice of technology: Make LNG, no existing gas lines to Europe


Snøhvit dehydration system Molecular sieve

Snøhvit’s molecular sieve

Hot Oil

Regeneration gas

Dry gas

(pressure, barA)<Temp, Celsius >

(64.9) <26.6 >

(63.0)<230>

(64.0)<27.6 >

(63.7)<27.5 >

(63.2) <233.0 >

Wet gas

Regeneration gas

Example of Molecular sieves


Summary Introduction, industrial examples and pipeline

These points have been discussed/explained:■ General facts about natural gas■ The dehydration system at:

● Troll (onshore), MEG injection and dehydration by cooling (turboexpanders)

● Kristin (offshore), dehydration by absorption (TEG system)● Snøhvit (onshore), dehydration by adsorption (molsieve)

■ Some of the issues related to transport of natural gas in pipelines


Dehydration


Natural gas processing

Principal sketch of a natural gas processing plant

Dehydration


Dehydration

Natural gas is commercially dehydrated in one of three ways

1. Absorption (Glycol dehydration)

2. Adsorption (Mol sieve, silica gel, or activated alumina)

3. Condensation (cooling) (Refrigeration with glycol or methanol injection)

Four glycols are used for dehydration and/or inhibition

1. Monoethylene Glycol (MEG) also called ethylene glycol (EG)

2. Diethylene glycol (DEG)

3. Triethylene glycol (TEG)

4. Tetraetylhene glycol (T4EG)

Dehydration

• Absorption and refrigeration with hydrate inhibition is the most common dehydration process used to meet pipeline sales specifications

• Adsorption processes are used to obtain very low water contents required in low temperature processes, for example LNG

• TEG is most common in absorption systems

• MEG is most common in glycol injection systems

Dehydration is the process of removing water from a gas and/or liquid


AbsorptionDehydration


Absorption Dehydration

Natural gas is dried by absorption, often in a countercurrent scrubbing unit

A liquid having a strong affinity for water is used as an absorbent

A good absorbent should have:

1. Strong affinity for water2. Low cost3. Non corrosive4. Low affinity for hydrocarbons and

acid gases5. Thermal stability6. Easy regeneration 7. Low viscosity 8. Low vapor pressure at the contact

temperature9. Low tendency to foam


TEG

DEG

TEG

TEG

Vapor pressure 25 C

Freezing point C

Viscosity (25 C)

Molecular weight

T4EGDEGMEG

-13 - -7TEGT4EGMEG

17- 49T4EGDEGMEG

62 – 194T4EGDEGMEG

Increasing values

Basic glycol properties


Basic glycol dehydration unit

Simplified flow diagram for a glycol dehydration unit. from the GPSA Engineering Data Book, 11th ed.



The glycol dehydration unit

Wet gas (no liquid water) enter bottom of absorber and flows countercurrent to the glycol. Lean glycol enters at the top

■ Absorber internal ● Tray

■ Bubble cap■ Valve■ Sieve

● Packing■ Berl Saddle, Raschig Ring……

ReactorOne, two pass trays

Bubble Cap

Bearl Saddle

Valve tray

Sieve trayBubble Cap tray


Maximize Contact areaand time Gas/glycol


Absorber designDesign parameters

■ Purity demand■ Working temperatures■ Working pressure■ Choice of absorbent

Design procedure

■ Mass balance circulate enough glycol to absorb the water in the gas

■ Gas rate tank diameter (flooding)■ Equilibrium analysis number of equilibrium

stages ■ Real analysis, have to take into account the

reaction kinetic and contact time between glycol and gas. Gives number of actual trays

■ Dryer glycol higher concentration differences higher reaction kinetichigher efficiency more expensive and heavier glycol regeneration system

■ Higher glycol circulation rate higher concentration differences higher reaction kinetic higher efficiency higher pressure drop more expensive and heavier pumps

Principal sketch assuming:

• Mass transfer are controlled by resistance on the gas side

• Straight operation and equilibrium lines of mol fraction water in the gas phase

stagesactualofNostagesEQofNo

..


Mol fraction water in glycol

Mol

frac

tion

wat

er

in g

as

Bottom of tower

Top of tower

Glycol flow

Gas flow

EQ lineOP lineYb*

Yb

Yt*

Yt

Y mol frac. Water gas phase

Y* EQ mol frac. Water gas phase


Glycol dehydration unit Working principle

• Minimum tray spacing 610 mm

• Flooding, foaming

Typical profiles of the mol fraction of water in glycol as a function of tower height. For tray and structural packing

Typical profiles of the mol fraction of water in gas as a function of tower height. For tray and structural packing

• Discrete and continues concentration profile

• Equilibrium assumption



Glycol regenerationAlternatives

A) Open stripping loopB) Closed stripping loop

C) Cold finger

Increased temperature

A) Any inert gas is suitable. Theoretically best to insert stripping gas between re boiler and surge tank

B) A closed stripping loop, isooctane can be used. Vaporizes at re-boiler temperature and condenses and can be separated from water in a three phase separator. High stripping gas rates with little venting of hydrocarbons. Glycol cons> 99.99% (w/w) has been achieved.

C) A cold finger is inserted into a bucket in the surge drum vapor space. A TEG mixture rich in water condenses out. This mixture is taped off. H2O partial pressure is lowered and lean glycol concentration is increased. 99.5-99.9 % (w/w) glycol has been achieved.


Rich TEG

Re boiler Heat Exchanger

A; Stripping gas

A; Wet stripping gas

Water

B; stripping gas

TEG unit

Cool

Heat

still column


Glycol regenerationComponent

Reboiler:

Temperature should not exceed 204 C (TEG) due to degradation.

Some degradation of glycol in contact with heat transfer surface maximum heat flux rates.

Heat provided with direct fired fire tubes immersed in the bath, hot oil, steam or electric resistance heating.

Stripping Colum:

Can be trayed or structural packed. Stripping gas lowers the partial pressure of H2O in the gas phase, and more water can be absorbed by the gas (Raoultslaw).

Surge drum:

Retention time >20 minBe able to hold all the re-boiler glycol, to allow repair or inspection of the re-boiler heating coil.

Flash tank:

Used to remove light hydrocarbons, CO2, H2S. Operation pressure 15% of the contactor operating pressure.

Filters:

Captures chemical impurities and solid particles. Pressure drop is measured and used as a replacing criteria.



Glycol absorption Pros and cons

Pros ■ Low initial cost ■ Low pressure drop across absorption towers ■ Recharging of towers present no problems ■ Materials that would cause fouling of some

solid adsorbents can be tolerated in the contactor

Cons■ Suspended matter, such as dirt, scale, and iron

oxide may contaminate glycol solutions■ Overheating of solutions may produce both low

and high boiling decomposition products■ The resultant sludge may collect on heating

surfaces, causing some loss in efficiency, or, in severe cases, complete flow stoppage

■ When both oxygen and hydrogen sulfide is present, corrosion may become a problem because of the formation of acid material in the glycol solution

■ Liquids such as water, light hydrocarbons or lubrication oils in inlet gas may require installation of an efficient separator ahead of the absorber. Highly mineralized water entering the system with inlet gas may, over long periods crystallize and fill the re-boiler with solid salts

■ Foaming of solution may occur with a resultant carry-over of liquid. The addition of a small quantity of antifoam compound usually remedies this problem



Dehydration by cooling


Refrigeration systemA refrigeration system lowers the

temperature of a fluid or gas below that possible when using air or water at ambient conditions.

■ Refrigeration systems are used for● Removing of water● Chilling natural gas for NGL

extraction● Chilling natural gas for

hydrocarbon dew-point control● LPG product storage● Natural gas liquefaction (LNG)

■ Refrigeration processes: ● Mechanical refrigeration

■ Compression (uses energy in form of work to pump heat)

■ Absorption (use energy in form of heat to pump heat, ammonia systems)

● Expansion refrigeration■ Valve expansion (Joule Thompson)■ Turbine expansion (Turbo expander)

Natural gas liquid fractions as a function of temperature at atmospheric pressure

Dehydration bycooling NGLrecovery


Refrigeration cyclePrincipal thermodynamic path

A-B,E cooled by heat exchange with the process gas.

B-C Natural gas is cooled by heat exchange with the refrigeration cycle. The gas temperature is lowered at constant pressure.

E-F’ Natural gas is cooled by isentropic (constant entropy S) expansion through a turbine (turbo expander), EF actual path.

B-D Natural gas is cooled by isenthalpic (constant enthalpy) expansion through a valve (Joule Thompson).


Thermodynamic pathLiquid recovery by refrigeration


Principal sketch of a refrigeration cycle

Refrigeration is achieved by vaporization at relatively low refrigerant pressure. The refrigerant can be a propane or sometimes a halogen of the Freon type.


Natural gas


Turbo expander cycle(Troll gas)

Dehydrated gas


Lean gas to pipeline compressorsTurboexpander

Suction drum

Dewpoint separator

Turbo expander process for NGL extraction

Phase envelope based Troll, dehydrated gas

1 Feed gas

1-2 Gas-gas heat exchanger

2-3 Suction drum

3-4 Turbine expander

4-5 Dewpoint separator


6-7 Compression

A hydrate inhibitor (MEG) is often injected upstream of the heat exchanger, if the gas is un-hydrated


-10

10

30

50

70

90

110

-170 -140 -110 -80 -50 -20 10 40

Temperature [C]

Pres

sure

[Bar

]

Path turbo expanderFeed gas phase envelopePath joule thompson

1 2

3

4 5

67


Joule Thompson cycle(Troll gas)

Inlet gas


(69)<-20.2>

Lean gas to pipeline compressors

TurboexpanderSuction drum

Dewpoint separator

Phase envelope based on Troll, dehydrated gas

Joule Thompson process for NGL extraction

1 Feed gas


2-3 Suction drum

3-4 Valve expander

4-5 Dewpoint separator


A hydrate inhibitor (MEG) is often injected upstream of the heat exchanger, if the gas is un-hydrated.


-10

10

30

50

70

90

110

-170 -140 -110 -80 -50 -20 10 40

Temperature [C]

Pres

sure

[Bar

]

Path turbo expanderFeed gas phase envelopePath joule thompson

1 2

3

45

6


Dehydration by adsorption



Adsorption describes any process where gas molecules are held onthe surface of a solid by surface forces. Adsorbents may be divided into two classes.

● Species is adsorbed due to physisorption and capillary condensation

● Species is adsorbed due to chemisorption (not much used in natural gas processing)

A sorbent must have the following properties:1. High adsorption capacity at equilibrium2. Large surface area3. Easily and economically regenerated4. Fast adsorption kinetics 5. Low pressure drop6. High cyclic stability (kinetic and capacity)7. No significant volume change (swelling shrinking)

Dehydrationby sorption



The commercial available sorbents can be divided into three broad categories:1. Gel

A granular amorphous solid (silica gel (SiO2), alumina gel Al2O3)2. Alumina

Hydrated form of aluminum oxide Al2O3, activated by drying off part of the hydrated water adsorbed on the surface

3. Molecular sievesAlkali metal crystalline aluminosilicates, very similar to natural clays

Example of sorbents:■ Silica gel (Gel type)

Outlet gas water content down to 10 ppm (v/v) and dew point -60 C can be achieved Regenerated between 120 and 200 C It adsorbs hydrocarbons, which are desorbed during regeneration Silica gel is destroyed by free water which causes the granules to burst, and react with bases

■ Activated alumina Al2O3Outlet gas water content <1 ppm (v/v), outlet dew point -73 C can be achieved Heavy hydrocarbons are adsobed but can not be desorbed during regeneration

■ Molecular sieves (zeolites) Outlet gas water content down to 0.03 ppm (v/v) , outlet dew point -100 C Water is adsorbed in a micro porous structureThe presence of carbonyl sulfide (COS) and carbon disulfide (CS2) should be avoidedThe adsorbent must be replaced frequently (about every three year)The water content in the feed must be low



Principal sketchAdsorbent system

http://www.uop.com/objects/96%20MolecularSieves.pdf

Flow sheet of a basic two tower adsorption system with regeneration

Molecular sieves

DehydrationBy sorption

Reg

ener

atio

n

Ope

ratio

n

Process gas

Regeneration gas

Regeneration gasProcess gas


Adsorption Concentration profiles

Active Zone

Mass transfer Zone

Equilibrium Zone

Dry gas

Wet gas

Variation of adsorption zones with time and height Schematic view of reactor bed with adsorption zones

• Equilibrium zone: Sorbent is saturated with water.

• Mass transfer zone: All the mass transfer takes place in this zone.

• Active zone: The sorbent has its full capacity for water, contains only residual water left from regeneration cycle.



Adsorption General point and re-generation

Design parameters■ Number of adsorption units

regeneration time■ Gas velocity and allowable

pressure drop diameter■ Good internal flow distribution avoid

channeling■ Proper pre-treating of the gas

● Degradation due to loss of effective surface area

● Degradation due to blockage of small capillary or lattice openings

■ Proper heat loss management (insulation internal/external) optimize regeneration

■ Proper heat recovery■ Possible to replace adsorbent

Principal sketch of reactor temperature during regeneration

T0-TA heating of the reactor

TA-TB evaporation and breaking of surface forces

TB-TC removing of heavy contaminants and residual water

TC Cooling, heat recovery phase



Summary dehydration

Different dehydration technologies have been discussed● Absorption

■ Glycol system» Trayed towers » Structural packing

● Concentration profiles ● Design guide lines ● System components

● Cooling■ System

● Compressor cooling● Turbo expander● Joule Thompson

● Adsorption■ Concentration profiles ■ Design guide lines ■ System component/operation


CO2 capture technology


CO2 capture from energy related sources

CombustionFossil fuel

Flue gasAir

Energy

CO2separation

CO2

N2 ,O2

Gasification/reforming

Fossil fuelH2, CO2

Air/O2 Steam

Energy

CO2separation

CO2

H2 Combustion

Air

N2 ,O2 , H2O

Energy

CO2 capture from large scale power plants is yet to be implemented


Overview CO2 capture technologies*

Separation task

Process Streams Postcombustion capture Oxyfuel Combustion capture Pre-Combustion Capture

CO2/CH4 CO2/N2 N2/O2 CO2/H2

Capture technologies Current Emerging Current Emerging Current Emerging Current Emerging

Solvents (Absorption)

Physical solvents

Chemical Solvents

Improved solventsNovel

contacting equipment Improved design of processes

Chemical solvents



n. a.

Biomimeticsolvents, e.g. hemoglobine-

derivatives

Physical solvent

Chemical solvents

Improved chemical solvents

Novel contacting equipment

Improved design of processes

Membranes Polymeric

Ceramic Facilitated transport Carbon

Contactors

Polymeric


Contactors

Polymeric

Ion transport membranes

Facilitated transport

Polymeric Ceramic

Palladium Reactors Contactors

Solid sorbents

Zeolites

Activated carbon

Zeolites

Activated carbon

Carbonates

Carbon based sorbents

Zeolites

Activated carbon

Adsorbents for O2/N2

separationPerovskites

Oxygen chemical looping

Zeolites

Activated carbon

Alumina

Carbonates

Hydrotalcites

Silicates

Cryogenic Ryan-

Holmes process

Liquefaction Hybrid processes Distillation

Improved distillation Liquefaction Hybrid processes

Separation task

Process Streams Postcombustion capture Oxyfuel Combustion capture Pre-Combustion Capture

CO2/CH4 CO2/N2 N2/O2 CO2/H2

Capture technologies Current Emerging Current Emerging Current Emerging Current Emerging

Solvents (Absorption)

Physical solvents

Chemical Solvents



Chemical solvents



n. a.

Biomimeticsolvents, e.g. hemoglobine-

derivatives

Physical solvent

Chemical solvents

Improved chemical solvents

Novel contacting equipment

Improved design of processes

Membranes Polymeric


Contactors

Polymeric


Contactors

Polymeric

Ion transport membranes

Facilitated transport

Polymeric Ceramic

Palladium Reactors Contactors

Solid sorbents

Zeolites

Activated carbon

Zeolites

Activated carbon

Carbonates

Carbon based sorbents

Zeolites

Activated carbon

Adsorbents for O2/N2

separationPerovskites

Oxygen chemical looping

Zeolites

Activated carbon

Alumina

Carbonates

Hydrotalcites

Silicates

Cryogenic Ryan-

Holmes process

Liquefaction Hybrid processes Distillation

Improved distillation Liquefaction Hybrid processes

* From IPCC special report on Carbon Dioxide Capture and Storage, 2005


Selcetion of CO2 capture technology

http://www.uop.com/gasprocessing/6010.html


Typical CO2 absorption loop

Amine AbsorberFeed

Gas KO Drum

Product Gas

KO Drum

Feedgas

Product gas

Lean-Rich Exchanger

Water Make Up

Water Wash Pumps

Rich Solvent Flash Drum

Flash gas

Lean Sol.Cooler(CW)

CarbonFilter

(Lean Sol)

Amine Regen-erator

HP Lean Pump

LP Lean Pump Regen.

Reboiler(LPS)

Acid Gas Condenser

(CW)

Regen. Reflux Drum

Reflux Pump

Acid gas


Summary of presentation

These points have been discussed/explained:

■ General facts about natural gas■ Industrial dehydration examples■ The different mechanism in gas/liquid separation■ Different dehydration technologies

● Absorption ● Cooling● Adorption

■ Sour gas removal


Thank you for your attention


Copyright

Copyright of all published material including photographs, drawings and images in this document remains vested in Aker Solutions and third party contributors as appropriate. Accordingly, neither the whole nor any part of this document shall be reproduced in any form nor used in any manner without express prior permission and applicable acknowledgements. No trademark, copyright or other notice shall be altered or removed from any reproduction.


Disclaimer

This Presentation includes and is based, inter alia, on forward-looking information and statements that are subject to risks and uncertainties that could cause actual results to differ. These statements and this Presentation are based on current expectations, estimates and projections about global economic conditions, the economic conditions of the regions and industries that are major markets for Aker Solutions ASA and Aker Solutions ASA’s (including subsidiaries and affiliates) lines of business. These expectations, estimates and projections are generally identifiable by statements containing words such as “expects”, “believes”, “estimates” or similar expressions. Important factors that could cause actual results to differ materially from those expectations include, among others, economic and market conditions in the geographic areas and industries that are or will be major markets for Aker Solutions’ businesses, oil prices, market acceptance of new products and services, changes in governmental regulations, interest rates, fluctuations in currency exchange rates and such other factors as may be discussed from time to time in the Presentation. Although Aker Solutions ASA believes that its expectations and the Presentation are based upon reasonable assumptions, it can give no assurance that those expectations will be achieved or that the actual results will be as set out in the Presentation. Aker Solutions ASA is making no representation or warranty, expressed or implied, as to the accuracy, reliability or completeness of the Presentation, and neither Aker Solutions ASA nor any of its directors, officers or employees will have any liability to you or any other persons resulting from your use.Aker Solutions consists of many legally independent entities, constituting their own separate identities. Aker Solutions is used as the common brand or trade mark for most of these entities. In this presentation we may sometimes use “Aker Solutions”, “we” or “us” when we refer to Aker Solutions companies in general or where no useful purpose is served by identifying any particular Aker Solutions company.

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