Download - BR - Subsea Oil Water Separation
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PETROBRAS TOTAL WORKSHOP
Subsea Oil Water Separation - OWS
SSAO OWS FOR MARLIM FIELD
France, June 2008
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OutlineOutline
1. Petrobras Motivations2. Scenario for the Prototype
3. Challenges & Petrobras Actions
4. Prototype Design Premises
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Motivation: High watercutsMotivation: High watercuts
2007 2010
Water treatment
Year
Water
2015
Increasing production of water - Platforms topped-up
Increasing cost of water treatment
Increasing production of water - Platforms topped-up
Increasing cost of water treatment
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Motivation: EnvironmentMotivation: Environment
Environment friendly solution Environment friendly solution
Reservoir
Subsea separation
Surface separation andtreatment
Multiphase
production
Water
discard
Water
discard
Multiphase
production
.
. .
. . .
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Year of discovery: 1985
Year of start-up: 1991
Total oil production:
Peak: 650,000 bpd, apr-2002
Currently: 410,000 bpd, jan-2007
Total water production:
295,000 bpd, jan-2007
Water depth: 500 m to 1,000 m
Campos Basin
N
Scenario for the Prototype in MarlimScenario for the Prototype in Marlim
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Host PlatformHost Platform
P37
FPSO Turret
Process capacity
Oil: 180,000 bpd
Water: 120,000 bpd
Gas: 3.1 million m3/d
Water depth: 890 m
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Scenario Definition HistoryScenario Definition History
P35 Scenario
Basic Design 1
June 2006
1st evaluation
Redesign
API: 18 degree
Emulsion:
Higher stability
2nd evaluation
Dec 2006
P37 Scenario
API: 22 degreeEmulsion:
Low stability
Sand: up to 100 ppm
Basic Design 2
march 2008
3rd evaluation
Jun 2008
Prototype
2009/2010
Water depth: 870mWell: MRL-141Well: MRL-102
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PWRI - Marlim Field PilotPWRI - Marlim Field Pilot
LP Tests
Prototype 2009/2010
HP Tests
Detailed design
Manufacturing
Integration
Tests
Field
Tests
2009/2010June 2008
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Project StatusProject Status
Basic Design for P37 aplication ready
Tests at P35 / MRL 94 well interventions ongoing
Contract discussions on going
Waiting for FMC Commercial propposal
Technical and Economical evaluation ready waiting for FMC negociating
conditions for submitting to the Directive Comittee
Structuring for the implementation of the next phase
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ScenarioScenario
Marlim Field :
High water production and platforms topped up
No dump well
High absolute revenue/high impact for the technology
P37 Platform :
Oil API: 22 degrees (instead of API 18 degrees)
Lower emulsion stability (high stability for lower
APIs)
Available room on the Turret
Fewer changings to acomodate
Available power (2,5 MWatt)
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ScenarioScenario
Production well MRL 141:
70% watercut in december 2009
Total flow rate: 3500 m3/day
Reinjection Well MRL - 488
High reservoir permeability: 7000 mD
Possible injection above fracture propagation pressure
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Main Challenges for Marlim OWSMain Challenges for Marlim OWS
Emulsion stability
Reinjection
Separation
10 ppm of solids
100 ppm of oil
Up to 60% water in oil
Pipe separator compact gravity separation
Schmoo / Corrosion / Scale
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BR Actions to deal with the challengesBR Actions to deal with the challenges
Separation Tests in Porsgrunn, Conceptual Studies and in depth lab
researchs on heavy oil separation
Qualification Programbefore/during the SSAO (MarlimOWS) implementation
Emulsion Stability
Testing several chemicals for definition of the demulsifierto be injected on the gas lift line stream
Reinjection Tests on P35: reinjection of produced water
Schmoo/Corrosion/Scale Testing chemicals for dosed injection and/or batch
injection
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Reinjection tests at P35Reinjection tests at P35
Slop Tank
Degasser
TO
Gravityseparator
Reservoir
tank
Injection
Pump
Filters
Heatexchangers
Production
Wells
MRL-94
Overboarding
swivel
Choke
90C
40C
P35 tests
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SchmooSchmoo
Slop Tank
Degasser
TO
Gravity
separator
Reservoir
tank
InjectionPump
Filters
Heat
exchangers
Production
Wells
MRL-94
Overboarding
swivel
Choke
90C
40C
P35 tests
Schmoo detected
and sampled
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Design Premises for the Prototype on P37Design Premises for the Prototype on P37
Production wellReinjection well
Platform
Oil: 22o.API
Chemical injection
Total flow: 18,500 bpd
Watercut @ start-up: 65%
Production well MRL-141
Reinjection well MRL-93
Reinjection above fracturing
pressure
Expected minimum performance
water removal: 70%OWS
Oil in Water < 100ppm
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Produced Water and Re-injection WaterSpecificationsProduced Water and Re-injection WaterSpecifications
Well production stream
Maximum sand content: 100 ppm
Free water (demulsifier action)
Seawater water injection has washed up the reservoir
Specifications for the re-injection water system: Maximum sand content: 10 ppm
Maximum oil content: 100 ppm
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Oil/gas and low water
Oil-water line
Gas line
Multiphase flow
Simplified Process Flow DiagramSimplified Process Flow Diagram
Reinjectionwell
Oil/gas and lowwater to the
platform
Production inlet
From the production well
1 2
3
45
6
Gas-liquid
separation
Waterpolishment
Solids management system not depicted
Reinjection
Pump
Liquid levelchamber
gravity oil-water
separation
Real time oil inwater monitor
Platform
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Process Flow Diagram / Process Designand Related TopicsProcess Flow Diagram / Process Designand Related Topics
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Conceptual FMC for MarlimConceptual FMC for Marlim
HxLxW: 8,4m x 29,5m x 8,5 m
298 toneladas
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Marlim Oil Water Subsea SeparationConcept SSAOMarlim Oil Water Subsea SeparationConcept SSAO
Oil-water overall separation
efficiency expectative > 70%
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Subsea Separation StationSubsea Separation Station
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Subsea Separation StationSubsea Separation Station
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Subsea Separation StationSubsea Separation Station
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System Artistic ViewSystem Artistic View
Oil water
subsea
separator
Multiphase line w/
low watercut
ProductionWell
Reinjection
Well