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# 1
An Overview of Offshore Concepts
Presented by: Christopher M. BartonDirector‐Business Acquisition
Expanding Facilities Knowledge Workshop‐Offshore Concept Selection
# 2
•Safety Minute
•Putting Energy Demand in Perspective
•Introduction to Offshore Concepts
•Field Development Planning
•Floating Platform Selection
•TLP Technology
•Spar Technology
•Semi technology
•FPSO Technology
An Overview of Offshore Concepts
# 3
Workplace Dangers
Safety Quiz:
It's important for employees to be able to spot potential dangers in and around the
workplace. Please study these pictures and see if you can spot the dangers yourself...
Safety Minute
# 8
Putting Energy Demand in Perspective
# 9
Coal, Oil and Natural Gas Will Remain Indispensable
8
# 10
Significant capacity additions required to meet demand
Source: Based on IEA World Energy Outlook 2007Natural decline forecast at 8% rateObserved decline forecast at 4.5% rate requires substantial investment
Oil Supply Challenge
# 11
Where Will the Energy Come From?
Increasing resource
nationalization;
diminished access
Non‐OPEC struggling
to increase production
Little spare OPEC
capacity
Depletion is real
Super majors will be
compelled to focus on
organic growth Deepwater will drive growth
# 12
Future Oil & Gas Deepwater Potential
# 13
Gulf of Mexico Lease Sales
Lease Activity Will Continue to Drive Deepwater GOM
# 14
Miocene & Lower Tertiary Discoveries Will Drive Deepwater GOM
# 15
Pre‐Salt Discoveries Will Drive Deepwater Brazil
# 16
Prolific Discoveries Will Continue to Drive Deepwater West Africa
# 17
Introduction to Offshore Concepts
# 18
The Offshore Industry60 Years Old and Still Growing
• First well drilled out of sight of land in 1947 in 20’ w.d.
• Today, we are drilling in 10,000’
• First offshore platform installed in 1947 in 20’
• Today, platforms are installed in depths exceeding 8,000’
• World’s tallest structure was installed offshore in 1979 in 373’
• Today, a fixed platform stands in excess of 1,800’
• First subsea tree installed in early 1960’s in less than 300’
• Today, subsea trees are installed in over 9,000’
# 19
June 1947 ‐ Oil & Gas Journal Feb 1959 ‐ Offshore Magazine
SparTLPCompliant TowerFPSOSemi
Floating Systems…then and now
# 20
Offshore Field Development
• Jacket type fixed steel structures
have traditionally proven to be
the most cost effective and
safest means of developing
offshore fields.
• Economics and increasing water
depths are driving the use of
other alternatives :
• Concrete structures
• Subsea systems
• Floating systems
# 21
Offshore Field Development
• The water depths in which fixed platforms are installed
vary from a few feet to as much as 1,850 ft
# 22
System types can be grouped into 2 categories:
1. Dry Tree Systems – Compliant Tower, TLP, Spar
2. Wet Tree Systems – TLP, FPSOs, Spar, Semi
Deepwater Development Tools
# 23
Truss Spar
Semi‐submersible (Semi)
Tension Leg Platform
• Proven ‐Many years of Operating history
• Functional ‐ Used for a large variety of functions, wet or dry tree
• Scaleable – Wide range of topsides payloads
• Adaptable – Applications worldwide
FPSO
There are four primary industry recognized wet and dry tree solutions; accepted because:
Predominant Floater Types
# 24
Motions and Loads are Controlled by…
Primary Secondary
TLPMooring System•Tendons
Hull Configuration•Column to Pontoon Volumetric Ratio
SparHull Configuration •Draft•Heave Plates
Mooring System •Taut•Synthetics
SemiHull Configuration •Column Stabilized•Small WP Area
Mooring System •Taut•Synthetics
Ship‐Shape
Hull Configuration •WL Length•Mass
Mooring System•Orientation•Head‐on Environment
# 25
5 10 15 20 25 30
Design Wave En
ergy
Period (sec)
Spread MooredSpread MooredVertically MooredVertically MooredVertical
Motions are Controlled by
Tendons
Vertical Motions are Controlled Hull Configuration
Natural Periods of Motion
Typical 100‐Yr Design Wave Spectrum
# 26
Comparison of Primary Characteristics
Issue TLP Spar Semi Ship‐Shape
Water Depth More Sensitive Less sensitive
Platform Motions
Excellent – Very low vertical motions, i.e. heave, roll and pitch
Good – Low vertical motions (pitch to 8‐10 deg). Sensitive to long period waves.
Motions limit application to wet
trees
Motions limit application to wet
trees
Transport Single piece complete Single piece hull Single piece complete Single piece complete
Installation Quayside deck lift and integration
Hull upending and offshore deck lift and
integration
Quayside deck lift and integration
Shipyard module lift and integration
# 27
Comparison of Primary Characteristics (continued)
Issue TLP Spar Semi Ship‐Shape
Mooring System
Vertical tendons Taut or semi‐taut spread mooring legs
Mooring Footprint
Small and compact, same dimensional
order as hull
Large, approximately 2X water depth. Impacts field development layout, but allows drilling flexibility.
TTR Support Short stroke tensioners
Air cans or long stroke tensioners
N/A N/A
Wellbay Conventional, within columns
Confined within moonpool
N/A N/A
Storage Capability
No Yes, but not typical No Yes, typical
Spread catenary or turret moored
# 28
• Combination of water depth, metocean conditions and topsides influence the
choice between a TLP, Semi, and Spar.
0
10,000
20,000
30,000
40,000
50,000
0 2,000 4,000 6,000 8,000 10,000
Water Depth (ft)
Facility Pa
yloa
d (st)
SparSemi
TLP
Generally Accepted Floater Application Ranges
# 29
Deepwater Production vs DrillingThe Gap is Closing Fast
# 30
Growth in Floating Production Systems
# 31
18 Spar Platforms
39 Semi FPS Platforms
24 Tension Leg Platforms
128 FPSO Vessels
Deepwater Floaters Installed
# 32
Deepwater Milestones
# 33
Field Development Planning
# 34
Feasibility Studies
Concept Studies
FEED Execute EPCI
• Identify development alternatives
• Determine technical feasibility
• Screen alternatives
• Select development concept
• Define development concept
• Design basis• Cost• Schedule• Execution Plan
• Detail design
• Construction
• Installation
• HUC
Phases of a Field Development Project
# 35
Project Success Hinges on Front End
# 36
Ability to Influence Cost
Co
nce
pt/
FE
EE
10%3%
P
40%
37%
CI
10%
Typical Project CostDistribution
Relative Level of Influence
on CostSolid execution strategy needed early in order
to “get it right”
D
7
# 37
It Takes A Village …. The Many Facets of Field Development Planning
TopsidesFacilities
Marine/RiserSystems
Geologists
Geophysicists
Petroleum Engineers
Reservoir
Drilling & Completion
Subsea Systems
Operations/Installation
Project Mgmt/Execution
Midstream, Sales, Marketing
Economics
Risk, Safety
Partners
BusinessMgmt
SubSurface
Surface
Business
# 38
Major Field Development Drivers
LowHighSafety, Reliability
LowHighPartners, PSAs, Taxes, RoyaltiesBusiness
Very HighVery HighOil / Gas Price
ModerateModerateOpex
ModerateHighSchedule to Peak HydrocarbonsSurface
ModerateHighFacility Capex, Drillex
HighHighProduction Profile
HighVery HighWell Count, Rate, RecoverySubsurface
Very HighVery HighRecoverable Reserves
UncertaintyImpactDrivers
# 39
Floating Platform Selection
# 40
• Reservoir characteristics are key
• Field layout / future expandability
• Riser options / platform motions
• Metocean criteria
• Deck requirements
• Local content requirements
• Drilling & completion strategy
• Robustness
• Risk issues & mitigating measures
• Execution plan and delivery model
Key Drivers for Floating System Selection
# 41
Floating Platform Selection Issues
LeastSomewhatSomewhatMostHull weight sensitivity to topside
BestBetterGoodGoodContracting Flexibility
QuaysideQuayside or floatover
Offshore or floatover
Quayside or floatoverTopside Integration
NoNoNo constraintNo constraintTTRs*
Only in mild environment
Motion optimization
neededNo constraintNo constraintSCR*
Semi‐taut spread wire or
poly
Semi‐taut spread wire or poly
Taut‐spread wire or poly
Steel tendonsStation‐keeping
YesNoNoNoStorage
NoYesYesYesDrilling/Workover
WetWetWet or dryWet or dryTrees
No practical limit
No practical limitNo practical limitUp to 1500Water Depth (m)
FPSO
(Ship Shape)
Semisub
(Four Column)
Spar
(Truss)TLPPlatform Configuration
# 42
HigherLower
Reservoir Mgmt and Productivity
HigherLowerProduction Reliability
LowerHigherOPEX Cost
LowerHigherDRILEX Cost
HigherLowerCAPEX Cost
Surface (dry‐tree)Total Subsea (wet‐tree)Criteria
Completion Strategy Drives Floater Selection
# 43
Dry Trees vs. Wet Trees
Key Driver: Wellbore Access
Dry Tree (Direct Vertical Access)
• Single drill center
• Lower OPEX and life cycle costs for medium and large developments
• Simpler hardware
• Minimize well intervention cost and downtime
• Less flow assurance risk
• Potentially higher recovery
• Difficult for semi due to motions
Wet Tree (Indirect Access)
• Multi drill centers
• Lower CAPEX, but potentially higher OPEX
• Minimize drilling costs and risks for large area extent reservoirs
• Minimize project schedule
• Maximize development plan flexibility
• Ultra deepwater capability not tied to host platform
• Maximize project economics for small developments
• More complex flow assurance issues
# 44
Number of Wells by Facility Type
# 45
Direct Well Access Riser Options
StricterHull MotionRequirements
StricterHull MotionRequirements
Direct Tensioned Riser Air Can Tensioned Riser Tubing Tie‐back RiserCompliant Vertical Access Riser (CVAR)Near or At‐Surface Completion
TTR
# 46
Indirect Well Access Riser Options
Steel Catenary Risers (SCR)Hybrid RisersFlexible Catenary Risers
StricterHull MotionRequirements
StricterHull MotionRequirements
• Placid GC 29. First Deep Water Free‐Standing Production Riser System. Installation, Drilling, Production, and Workover from the Same Semi.
• Enserch GB 388.
# 47
DEVELOPMENT OPTIONS
Dry Trees Dry TreesWet
TreesTLP SPAR
Floating Production
Unit
Semi-Submersible FPSO
DryTreeUnit
Tender Assist Drilling
MODU Drilled
Permanent Platform Facilities
FSO
DRILLINGSTORAGE &
EXPORTSUBSTRUCTURES
Selection of potential development options
Development Option Components
Facilities Elements
Development Option Strategies
All WetTie-backs
Wet &Dry
SubseaTiebacks
Pipeline
Option Identification – Building Blocks
# 48
Hull Size
Total FacilityPayload
Total FacilityPayload
TopsideWeight
• Type, Amount Boosting• Workover Rig• Wax Hydrate Management
• Oil / Gas ProductionThroughput
• Dry or Wet Trees• Drilling or No Drilling
• Drilling,Completions
• Flow Assurance• Boosting• Intervention
• Well Count• Well Location• Production Profile
• Geometry• Connectivity
• Export RiserWeight
• Export RiserSize, Type
• Integrated OilStorage / Shuttle
• Oil Pipeline
• Production RiserWeight
• Station KeepingWeight
• ProductionRiser Size, Type
• Station KeepingType
Roadmap for Establishing Size of Floating Platform
PipelineInfrastructure
• Water Depth• Metocean
ReservoirReservoir
Size(Recoverable
Reserves)• Geology• Rock Properties
• Depth Below M/L• Salt Layer
Fluid Properties(P, V, etc.)
# 49
TLP Technology
# 50
TLP Statistics
Installed : 24
First: 1984, Hutton, Conoco
Locations: North Sea, Angola,
Gulf of Mexico, Indonesia
and Equatorial Guinea
Deepest: 4,674 ft., Magnolia
GB783/84
# 51
Current TLP Installed Base – by Location
# 52
– Topsides• Production Facilities• Drilling Systems• Utilities• Accommodations & Helideck
– Hull• Columns• Pontoons• Pontoon Extensions• Riser Porches
– Mooring System• Tendon Porches• Tendons• Foundations
– Riser System• Drilling and Production Risers• Trees and associated components
TLP Components
Topsides
Pontoons
Columns
Tendons
# 53
Proprietary TLP Designs and Technology Providers
MODEC DESIGN
SBM ATLANTIA DESIGNS
FLOATEC DESIGNS
# 54
Typical Functions of a TLP
Functions ConsideredFull PDQ:• Fully Self Contained• Export to Pipeline or FSO
Wellhead Platform:•Drilling only (on platform)
• Support of Dry Trees• Export to FPSO
Tender Assisted Drilling:•Drilling Systems on TAD Vessel• Benign Metocean Regions
Wet Tree Application with Production and Quarters:•No Drilling• Export to Pipeline or FSO
# 55
TLP Drilling & Production Configurations
Tender assist drilling & production mode
Platform drilling & production mode
Wellhead platform mode with remote production
# 56
Kizomba A ETLP Configuration
Functions and Particulars :
• Drilling
• Well Intervention
• Dry Tree Manifold
• Displacement ‐ 53,033 mt
• Draft ‐ 34 m
• 36 TTRs
• Tendons ‐ 4 x 2
Water Depth ‐ 1,178 m (3,865 ft)
FPSO
SWHP
# 57
Magnolia ETLP Configuration
Functions and Particulars :
• Full production
• Workover rig
• 15,230 st total topsides payload
• 8 TTRs
• Import / export risers
• 4 x 2 stepped tendons
Water Depth – 4,674 ft
# 58
Typical TLP Tendon Make‐up
Connected to Tendon Porch
MWL +3937 ft
Mudline
Pretension 2750 kips
TTS
TTS, TBS and MB1 to MB 14ALL Approx. 240 ft long
TBS
1
2
3
14
4
5
Segments 1 to 14
Each Segment (240 ft) consists 60 ft pipes girth welded
# 59
Stepped Tendon System
Open Tendon Porch
Closed Tendon Porch
TLP Tendon Porches
# 60
Free Standing Tendon Installation
TTS
Mud lineTBS
WD 1200 m(3937 ft)
Main Pipe
Water Surface
Buoys Connected100 ft from top of tendon
Buoy Dimension:18’ OD x 50 ft long
# 61
TLP Riser Stack‐ups
Hanging Hydraulic Tensioners
# 62
Conventional TLP Tensioners
# 63
Typical Wellbay Layout(TLP Supported Risers)
# 64
Project Photos
# 65
Hull Component Fabrication
# 66Panel Line Work
# 67
Hull FabricationDry Dock Based
# 68
Hull Fabrication at QuaysideLand Based
# 69
Preparing for Loadout
# 70Hull Loadout
# 71Hull Float On
# 72
Mars TLP
Ursa TLP ‐ BargeRam/Powell TLP
Hull Transportation
Kizomba TLP
# 73Hull Sailaway
# 74
Hull Float‐Off(Ram/Powell TLP)
# 75
Deck/Hull Quayside IntegrationLand Based Crane
# 76
System DeliveryDeck Lift & Integration
(Ram/Powell TLP)
# 77
System Delivery
Deck Lift & Integration(Ram/Powell TLP)
# 78
System DeliveryDeck Lift & Integration
(Ram/Powell TLP)
# 79
Deck Lift & Integration(Kizomba “A” ETLP)
# 80
Deck Integration(Magnolia TLP)
# 81
Platform Commissioning(Performed at Quayside)
# 82
Platform Dry Transport
# 83
Platform Dry Transport(Next Stop ‐ Angola)
# 84 Platform Wet Tow to Location
# 85
TLP Pile Fabrication and Pre‐Installation
# 86Tendon Pre‐Installation
TLP Tendon Pre‐Installation
# 87
TLP Topsides Installation ‐ Offshore
# 88
Platform Commissioning(Brutus TLP)
# 89 TLP Installed
# 90
Spar Technology
# 91
Spar Statistics
Installed : 18
First: 1996, Neptune, VK 826
Deepest: Perdido 8,008 ft.
Alaminos Canyon 857
Construction: 0
Locations: Gulf of Mexico, Malaysia
# 92
Spar Features
Truss
Hard Tank
Topsides
Soft Tank
Unconditionally Stable
Failsafe ballast system
Simple ballast system
Mooring Line Failure not Catastrophic
Redundancy
Spar continues to float
Down flooding difficult
Risers Protected from Loop Currents and Waves
# 93
Current Spar Installed Base – by Location
# 94
Spar Hull Diameter Comparison
# 95
Current Installed Base
# 96
Spar Flexibility and Scalability
Holstein Truss Spar
• # Dry Trees – TTR’s: 20
• # SCR’s: 2
• Pay Load: 37,000 mt
• Estimated Reserves: 400 MBOE
Red Hawk Cell Spar• # Subes Trees: 2• # SCR’s: 3• Pay Load: 5,460 mt• Estimated Reserves: 50 MBOE
# 97
Current Installed Base
# 98
Hull Design Drivers
• Payload• Hard tank compartmentation • Ballasting
– Variable (sea‐water)– Fixed (magnetite)
• In‐hull storage of chemicals, diesel, etc. • Fabrication & installation
– Yard limitations (skidway spacing, quay depth, cranes)– Heavy lift transport vessel– Offload draft– Wet tow & up‐end (keel tank sizing)– Topside lift
• Performance criteria (pitch, surge & heave)
# 99
Front Runner
Devils Tower
Medusa
Geotechnical Considerations
• Bathymetry (bottom contours, escarpments, etc.)
• Geotechnical (hazards, soils, faults, etc.)
# 100
Spar Mooring Systems
MWL
8200
'-0"
R4 STUDLESS CHAIN
3 SEGMENTSPOLYSTER ROPE
(-) 8200'-0"ANCHOR
SUCTION PILE8000'-0"
TRUSS SPAR PLATFORM
SCR (TYP.)
SCR PORCHES
ELEVATION VARIES
R4 STUDLESSANCHOR CHAIN
SCR (
TTR
10°-14°(TYP.)
MWL
MOORING / RISER ELEVATION
RQ4 STUDLESS CHAIN
SPIRAL STRAND STEEL WIRE
ANCHOR TION PILE
OR CHAIN
SCOPE FROM FAIRLEAD
TRUSS SPAR PLATFORM
Steel Wires Synthetic Ropes
• Chain‐Wire‐Chain system• Driven or suction anchor piles• Grouped or equally spread• Sized for both intact and
broken line conditions• Active system
# 101
Spar Risers
• Direct vertical access wells (Dry Tree)– Top‐tensioned, rigid risers – single or double cased
• Import flowline risers (Wet Tree)– Steel catenary– Flexible pipe
• Export pipelines risers– Top‐tensioned– Steel catenary– Flexible pipe
• Control umbilical bundles
# 102
Riser System Options: Wet Trees
Riser Hang‐off Porch:
Flexjoint
Stress Joint
Pull Tubes:
Flexibles
SCR’s
# 103
Riser System Options: Dry Trees
Buoyancy Can
Hydraulic
Multi-riser Buoyancy Can
# 104
Spar Buoyancy Can Tensioner(non‐Spar supported)
# 105
Spar Ram Type Tensioners(Spar‐supported)
# 106
Riser Options (Flexibility): Combination Dry & Wet Tree
Pull Tubes, SCR’S OR Flexibles
Dry Tree Riser Slots, Top Tensioned Buoynacy Cans
# 107
Centerwell Drivers
• Dry trees
– Number of well slots
– Riser make‐up / buoyancy can size
– Tree size and access requirements
– Drilling riser slot
• Wet trees and umbilicals
– Number
– Sizes (hang‐off loads)
– Azimuths
• Pump casings, disposal caisson, cuttings chute, exhaust ventilation, etc.
# 108
Centerwell Arrangement ‐ Example
Export Lines (2)
Drain Sump
Buoyancy Cans (8)
Misc.Utilities
Flowlines (10)
Umbilicals (5)
# 109
Topsides Drivers
• Payload ‐Weight, Mass, VCG & HCG
– Initial and future
– Lift and operating conditions
• Wind sail areas (directional) & elevation of resultant wind pressure
• Prevailing wind directions
• Wave crest elevation & air gap (set deck elevations)
• Lift equipment constraints on topside geometry
• Centerwell access
# 110
PanelLine
RingSections
1/8 Sections
1/4 Sections
1/2 Sections
FullSections
Spar Hard Tank Build Philosophy
# 111
Upper Half Ring Section Assembly
Lower Half Ring Section Assembly
Ring Section Mating
H
HT Half Ring Assembly and Mating Methodology
# 112
First Cutting of Steel Center Bulkhead Assembly 1/8 Segment Assembly
Segment Full Welding Shifting Segment to Erection Shifting Center Bulkhead
HT Segments & Center Bulkhead Sub‐Assembly
# 113
UPPER SECTION
BLOCK EBLOCK F
LOWER SECTION
BLOCK B BLOCK A BLOCK HBLOCK GBULKHEAD
BLOCK C BLOCK D BULKHEAD
Hard Tank Half Ring Sections Assembly
# 114
1 2 3
4 5 6
Hard Tank Half Ring Sections Mating
# 115
Hard Tank Sections Mating & Joining
# 116
Soft Tank Block Erection
# 117
Spar Hull Assembly
# 118
Spar Hull Ready For Loadout
# 119
Spar Hull Load‐out
# 120
Spar Hull Load‐out
# 121
Spar Hull Tie‐Downs
# 122
Spar Hull Ready for Transport
# 123
Spar Hull Transport
# 124
Spar Hull Offload
# 125
Hull Wet Tow to Site
# 126
Spar Hull Wet Tow and Upend
# 127
Hull Upend Sequence
Wet Tow Ballast
# 128
Post Up‐end Stages
Post Upend Fixed Ballast Set TWD Install Moorings Remove TWD
Install SCRs Set Topside Topside Set Operating
# 129
Mooring System Components
# 130
Anchor Types
Suction PilesSuction Piles60 st 60 st –– 250 st250 st
Driven PilesDriven Piles150 st 150 st –– 230 st230 st
Driven PilesDriven Piles150 st 150 st –– 230 st230 stDrag AnchorsDrag Anchors30 st 30 st –– 50 st50 st
# 131
Chain Jacks
Set Work Deck
Mooring Installation
# 132Temporary Work Deck
# 133
Anchor Chain Hook‐up
# 134
Ready for Topsides Installation
# 135
Topsides Installation
# 136 Topsides Installation
# 137
Topsides Installation
# 138
Spar Topsides Installation (Floatover)
# 139
Spar Riser Installation
Seafloor Stress‐Joint& Connector
Casing
Keel‐JointBuoyancy Can
Tapered Stress & CrossProduction Riser
Keel and Transition J
FlowlineJumpers & Umbilicals
Tieback Connector
Stem Centralizers
Buoyancy Can
Surface Wellhead & Tree
Subsea Wellhead
Tapered Stress & CrossProduction Riser
Keel and Transition J
FlowlineJumpers & Umbilicals
Tieback Connector
Stem Centralizers
Buoyancy Can
Surface Wellhead & Tree
Subsea Wellhead
# 140
Tapered Stress & Crossover JointsProduction Riser
Keel and Transition Joints
Flowline Jumpers & Umbilicals
Tieback Connector
Stem Centralizers
Buoyancy Can
Surface Wellhead & Tree
Subsea Wellhead
Tapered Stress & Crossover JointsProduction Riser
Keel and Transition Joints
Flowline Jumpers & Umbilicals
Tieback Connector
Stem Centralizers
Buoyancy Can
Surface Wellhead & Tree
Subsea Wellhead
Jumpers Upper Stem
Tree & Access Platform
Can Installation
Jumper Hoses
Spar Riser Installation
# 141
Spars Installed
# 142
Semi‐FPS Technology
# 143
Semi‐FPS Statistics
• Operating : 39
• First: 1975, Argyll, Hamilton
• Deepest: 7,920 ft, MC920
Independence Hub
• Locations: Worldwide
# 144
Current Semi‐FPS Installed Base – by Location
# 145
Topsides•Production Facilities•Utilities•Accommodations
Hull•Columns•Ring Pontoon
Mooring System•Polyester/wire•Anchor piles (suction/driven)
Riser System•Steel Catenary Risers
Topsides
Moorings
Columns
Pontoons
Semi‐FPS Components
# 146
Conventional Production Semi‐FPS
# 147
Conventional Production Semi
• Column extended for deep draft• Reduced column/pontoon size for better motion
Deep DraftSemi
Pre‐Katrina
The Evolution of the Post‐Katrina Deep Draft Design
Deep DraftSemi
Post‐Katrina
• Column extended for air gap• Increased column spacing for stability
# 148
ATANTIA
DEEP DRAFT DESIGN
AKER KVAERNER
DEEP DRAFT DESIGNGVA / KBR DESIGN
EXMAR DESIGN MOSS MARITIMEDESIGN
FLOATECDEEP DRAFT DESIGN
Proprietary Semi‐FPS Designs and Technology Providers
# 149
Typical Semi Topsides
# 150
Typical Semi‐FPS Hull Block Breakdown
# 151
Semi‐FPS Hull Construction(Nodes Sub‐block Assembly)
# 152
Semi‐FPS Hull Construction(Pontoon Sub‐block Assembly)
# 153
Semi‐FPS Hull Construction(Erection of Nodes Sub‐block)
# 154
Semi‐FPS hull Construction(Pontoon Erection)
# 155
Semi‐FPS Hull Construction(Consolidating Pontoons in Dry Dock)
# 156
Semi‐FPS Hull Construction(Consolidating Pontoons in Dry Dock)
# 157
Semi‐FPS Hull Construction(Undocking of Pontoons)
# 158
Semi‐FPS Hull Construction(Undocking of Pontoons)
# 159
Semi‐FPS Hull Construction(Column Block Assembly)
# 160
Semi‐FPS Hull Construction(Consolidating Column Blocks)
# 161
Semi‐FPS Hull Construction(Erection of Column Blocks)
# 162
Semi‐FPS Hull Construction(Completed Lower Hull Ready for Transport)
# 163
Semi‐FPS Hull Dry Transport
# 164
Semi‐FPS Topsides Construction
# 165
Hull is moored, ballasted and in position
Barge is pulled to site
Hull is dry‐transported, offloaded and wet‐towed to installation site.
Marine Mating (Hull and Topsides)
Topsides is skidded onto barge
Topsides Integration (Floatover Option)
Semi‐FPS Topsides Integration ‐ Floatover
# 166
Semi‐FPS Topsides Integration(Mating Completed)
# 167
Land‐based Semi‐FPS Construction
# 168
Topsides Integration
# 169
Semi‐FPS Topsides Integration(Single Lift)
# 170
Integrated Semi‐FPS Dry Transport
# 171
Semi‐FPS Wet Tow to Field
# 172
Semi‐FPS Wet Tow to Field
# 173
Semi‐FPS in Operation
# 174
FPSO Technology
# 175
FPSO Statistics
First
Deepest
Operating
1977
Castellon, Shell
6,086 ft., Roncador
128
WorldwideLocations
# 176
Current FPSO Installed Base – by Location
# 177
Ship‐shape FPSO Components
Hull(Conversion or New Build)
Topsides
Turret and Mooring(Permanent or disconnect)
# 178
Round FPSO Components
# 179
FPSO Layout
# 180
FPSO Topsides Modules
P1
P2
P3
P4P5P6P7
P8
S1
S2S3S4S5
S6S7
S8
Main E&I Bldg
Seawater Water Injection
Seawater Filtration & Utilities
Production Manifolds
Oil Dehydration
LLP Gas Compression
HP & HHP Gas Compression
Gas Dehydration
Power Generation
Power Generation (3 trains)
Seawater Deaeration
Production Manifolds
Oil Dehydration
Future Module
LP & MP Gas Compression
Oil Offloading
# 181
# 182
FPSO Station Keeping Key Considerations
• Permanent vs. Disconnectable
• Turret Location on the Hull (internal vs external)
• Mooring Material
– Polyester vs. Steel Wire
• Anchor Selection
– Suction Piles vs. Vertically Loaded Anchors
• Dependent on:
– Weather conditions
– Water depth
– Number/diameter of risers
# 183
FPSO Mooring Systems
# 184
FPSO Mooring Components
# 185
FPSO Construction – Ship Shape
# 186
FPSO Construction – Ship Shape
# 187
FPSO Construction – Round Shape
# 188
FPSO Construction – Round Shape
# 189
Round FPSO Dry Transport
# 190
Round FPSO Wet Transport
# 191
FPSO’s in Transit
# 192
Ship‐shape FPSO’s in Operation
# 193
Round FPSO in Operation
# 194
The Next Generation FPSO
The Azurite FDPSO
• Combines the benefits of a MODU and a floating storage, production and offloading unit
# 195
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