Confidential © 2017 Aker Solutions
Subsea Processing
Solutions for Mature
Fields with Large
Water Cut
February, 2017
Marco Gabelloni, BD SPA
Confidential © 2017 Aker Solutions
Agenda
■ Introduction
■ Case description
■ Design philosophy
■ Subsea separation technology
■ Subsea boosting technology
■ Summary
February 2, 2017 Slide 2
Confidential © 2017 Aker Solutions
Aker Solutions
Expertise
From subsea to surface and concept to
decommissioning, our technical expertise
and strong partnerships provide energy
companies what they need to succeed
February 2, 2017 Slide 3
Subsea Production Systems
Field Planning, Feasibility
and Concept Studies
Lifecycle Services
Carbon Capture, Utilization and Storage
Advanced Subsea Technologies
Workover Systems
Maintenance, Modifications
and Operations
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■ In-depth coverage of the entire
spectrum of field development
aspects
■ Global presence in main oil and
gas hubs
February 2, 2017 Slide 4
Front End Integrated Global Offering
■ Pulling together all the facets of Aker
Solutions and its partners to provide
an integrated solution
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■ Existing tie-in ■ Water depth approx. 400 m
■ 8 production wells
■ Water production is increasing
■ FPSO ■ Existing topside facility, also
processing other fields
■ Supplying power, lift gas
■ Receiving produced water and
hydrocarbons
February 2, 2017 Slide 5
Case Study Introduction
■ Fluid ■ API: 25
■ Topsides produced water
handling capacity ■ Rapidly increasing water cut
■ Tie-in of new field ongoing, need to
reduce water load from Template A
and B down to ~2 000 m3/d
■ Subsea operating conditions ■ 28 bar and 65°C
■ ~10 years of remaining production
■ Water cut ranging from 80 to 95+%
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■ Topside debottlenecking and subsea
boosting are the main purposes of the
subsea system ■ Water separation and hydrocarbon boosting
■ Need to polish and dispose of produced
water
■ Utilize topside capabilities before adding
complexity in subsea system
■ Low solids production rate ■ Separator equipped for sand flushing
February 2, 2017 Slide 6
Design Targets and Input
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Design Philosophy – Performance Requirements
■ System performance requirements,
subsea vs. topside ■ What is a good balance between cost,
complexity and robustness?
■ What is ‘good enough’ for the system
subsea requirements?
■ Is there any step change in subsea
system capability that enables large
overall savings? ■ Produced water injection or discharge
February 2, 2017 Slide 7
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■ Reinjection into reservoir is a mature
solution ■ Numerous topside solutions
■ Achieving injection from subsea facility ■ Potential to improve cost and reliability
■ OiW target - case specific
■ Online OiW monitoring
■ Potential produced water technologies ■ Deoiling hydrocyclones
■ Compact flotation unit
■ Combination of compact and large subsea
tanks for added robustness
February 2, 2017 Slide 8
Design Philosophy – Subsea Produced Water Handling
Confidential © 2017 Aker Solutions February 2, 2017 Slide 9
High Level System Sketch
3-phase gravity
separator FPSO MPP
Disposal
Injection
WIP
CFU
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Separation System Design - Main Component Sizes
1000 mm
3000 mm
2800 m
m
0
13000
2250
12610
12450
11840
1800
2390
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■ Primary stage: Three phase horizontal gravity separator ■ Proven, reliable, robust
■ Simple process control
■ Produced water treatment: Compact Flotation Unit (CFU) ■ Topside proven, high turn-down capability, good performance, low dP, robust
■ Vessel jetting system installed ■ Simple and cheap for fields with low sand production
■ Option to connect from ship to operate
February 2, 2017 Slide 11
Subsea Separation Technology
Confidential © 2017 Aker Solutions February 2, 2017 Slide 12
Subsea Boosting Technology Liq
uid
Booste
rTM
Hybrid
Booste
rTM
MultiB
ooste
rTM
PO
WE
RJum
pT
M
Confidential © 2017 Aker Solutions February 2, 2017 Slide 13
Technology Maturity Overview
Component TRL Comment
Separator
Vessel 7 Installed subsea
Internals 7 Subsea proven under relevant conditions
Compact Flotation Unit 2 Topside proven, new operating conditions subsea
Water Injection Pump 7 Installed subsea
Multi-phase Pump 3 Qualification ongoing
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■ Total subsea system water removal ~90%
February 2, 2017 Slide 14
Overall System Performance
0
2,000
4,000
6,000
8,000
10,000
12,000
14,000
16,000
2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030
Wa
ter
rate
(m
3/d
)
Year
Water to topside Water production from wells
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Summary
■ Subsea oil-water separation can
extend life of mature fields with high
water cut and debottleneck topside
facilities
■ Subsea boosting can compensate
for increased pressure drop due to
increased water cut
■ Integrated evaluation of topside and
subsea modifications is key for
optimized and cost-effective solution
February 2, 2017 Slide 15
Confidential © 2017 Aker Solutions
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February 2, 2017 Slide 17
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