spe artic technology 2015 subsea separation as enabler for
TRANSCRIPT
Subsea separation as enabler for subsea artificial lift solutionsBjørgulf Haukelidsæter Eidesen | Statoil ASA
Presentation Outline
What is subsea processing?IntroductionBackgroundMotivationTroll PilotTordis SSBIOil‐Water separationGas‐Liquid separationConclusion
What is subsea processing?
Definition:“Any active handling or treatment of produced fluids at or below the seabed”
SeparationPumping – for boosting or injectionCompression
Introduction
New opportunities
Integrated approach
One plant
INTERACTIONINTERACTION
Background
Subsea Processing Pioneer
Re‐using existingtechnology
Game changers
Motivation
Profitability
Host capacity/complexity
Enabling new solutions
Carbon efficiency
Troll Pilot
OiW content 500 ppm15 years subsea
Reduced WI wellhead pressure2000‐2500 Sm³/d WI rate
Topside capacityReduced gas lift required
Troll Pilot
Troll C
Tordis SSBI
OiW content 500 ppm
Installed subsea for 7 years
Separator inlet pressure 32 bar
Easy to operate
Boosting increases oil recovery
Tordis SSBI
Horisontal gravity separator
Oil‐Water Separation
Moving from 1000 ppm to 100 ppm OiW
Next is 10 ppm OiW
New possibilities
Pipe separator, Statoil patent
Simplified process overview
100 ppmoil in water
10 ppmoil in water
Pipeseparator
Hydro‐cyclones
Water injectionpump
Well
100 ppm
Pipeseparator
Water polishingunits
Choke
Gas/oil
Water injectionpump
Well or Sea
10 ppm
5 barg
EjectorOil and Gas Flowline to host
A Game Changer1000 ppm oil in water (OiW):Re‐injection of water in dump wells or some reservoirsReduced need for artificial liftReduced carbon footprintSubsea pre‐processing of water for topside cleaningLess need for riser capacity at high water cuts
100 ppm OiW:Possible to re‐inject in more reservoirsReduced need for/size of topside processing
10 ppm OiW:All subsea produced water treatmentPossibility for discharge to sea in some areasRe‐injection possible in most reservoirs
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Gas‐Liquid Separation
Several applications worldwide
Carbon Efficiency
Artificial lift
Economics
Horisontal gravity separator
Conventional topside process
Flowline
3
What happens if we move the first stage separator to subsea?
Gas‐Liquid Separation Riser base
A different design philosophyOne plantSimplified topsideReduced CAPEXReduced OPEXMature technology
Flowline
3
A new type of solution
Flowline
3
Simplified flow assuranceSimplified artificial liftSimplified topside processReduced CAPEX and OPEXIncreased recoveryCarbon efficiency
Conclusion
Enabling new solutions
Game changing
Carbon efficiency
Simplifying and enablingbetter artificial lift solutions
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