Offshore Concepts

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An Overview of Offshore Concepts

Presented by: Christopher M. Barton

Director‐Business Acquisition

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•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

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# 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

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Coal, Oil and Natural Gas Will Remain Indispensable

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Significant capacity additions required to meet demand

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# 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

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Gulf of Mexico Lease Sales

Lease Activity Will Continue to Drive Deepwater GOM

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Miocene & Lower Tertiary Discoveries Will Drive Deepwater GOM

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Prolific Discoveries Will Continue to Drive Deepwater West Africa

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Introduction to Offshore Concepts

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The Offshore Industry 60 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’

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June 1947 ‐ Oil & Gas Journal _{Feb 1959 ‐ Offshore Magazine}

Spar TLP Compliant Tower FPSO Semi Floating Systems…then and now

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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

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Offshore Field Development

• The water depths in which fixed platforms are installed

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System types can be grouped into 2 categories: 1. Dry Tree Systems – Compliant Tower, TLP, Spar

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# 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

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Motions and Loads are Controlled by… Primary Secondary TLP Mooring System •Tendons Hull Configuration •Column to Pontoon Volumetric Ratio Spar Hull Configuration •Draft •Heave Plates Mooring System •Taut •Synthetics Semi Hull Configuration •Column Stabilized •Small WP Area Mooring System •Taut •Synthetics Ship‐ Shape Hull Configuration •WL Length •Mass Mooring System •Orientation •Head‐on Environment

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# 25 5 10 15 20 25 30 Design Wave Ene rgy Period (sec) Spread Moored Spread Moored Vertically Moored Vertically Moored Vertical Motions are Controlled by Tendons Vertical Motions are Controlled Hull Configuration Natural Periods of Motion Typical 100‐Yr Design Wave Spectrum

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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

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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 _{stroke tensioners}Air cans or long 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

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• 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 Facil ity Payload (st) Spar Semi TLP Generally Accepted Floater Application Ranges

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Deepwater Production vs Drilling The Gap is Closing Fast

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# 31 18 Spar Platforms 39 Semi FPS Platforms 24 Tension Leg Platforms 128 FPSO Vessels Deepwater Floaters Installed

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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

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Ability to Influence Cost Concept/FEE E 10% 3% P 40% 37% C I 10% Typical Project Cost Distribution Relative Level of Influence on Cost Solid execution strategy needed early in order to “get it right” D

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# 37 It Takes A Village …. The Many Facets of Field Development Planning Topsides Facilities Marine/Riser Systems Geologists Geophysicists Petroleum Engineers Reservoir Drilling & Completion Subsea Systems Operations/ Installation Project Mgmt/ Execution Midstream, Sales, Marketing Economics Risk, Safety Partners Business Mgmt Sub Surface Surface Business

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Major Field Development Drivers Low High Safety, Reliability Low High Partners, PSAs, Taxes, Royalties Business Very High Very High Oil / Gas Price Moderate Moderate Opex Moderate High Schedule to Peak Hydrocarbons Surface Moderate High Facility Capex, Drillex High High Production Profile High Very High Well Count, Rate, Recovery Subsurface Very High Very High Recoverable Reserves Uncertainty Impact Drivers

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• 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

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# 41 Floating Platform Selection Issues Least Somewhat Somewhat Most Hull weight sensitivity to topside Best Better Good Good Contracting Flexibility Quayside Quayside or floatover Offshore or floatover Quayside or floatover Topside Integration No No No constraint No constraint TTRs* Only in mild environment Motion optimization needed No constraint No constraint SCR* Semi‐taut spread wire or poly Semi‐taut spread wire or poly Taut‐spread wire or poly Steel tendons Station‐keeping Yes No No No Storage No Yes Yes Yes Drilling/Workover Wet Wet Wet or dry Wet or dry Trees No practical limit No practical limit No practical limit Up to 1500 Water Depth (m) FPSO (Ship Shape) Semisub (Four Column) Spar (Truss) TLP Platform Configuration

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Higher Lower Reservoir Mgmt and Productivity Higher Lower Production Reliability Lower Higher OPEX Cost Lower Higher DRILEX Cost Higher Lower CAPEX Cost Surface (dry‐tree) Total Subsea (wet‐tree) Criteria Completion Strategy Drives Floater Selection

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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

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# 45 Direct Well Access Riser Options Stricter Hull Motion Requirements Stricter Hull Motion Requirements Direct Tensioned Riser Air Can Tensioned Riser Tubing Tie‐back Riser Compliant Vertical Access Riser (CVAR) Near or At‐Surface Completion

TTR

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Indirect Well Access Riser Options Steel Catenary Risers (SCR) Hybrid Risers Flexible Catenary Risers Stricter Hull Motion Requirements Stricter Hull Motion Requirements • Placid GC 29. First Deep Water Free‐Standing Production Riser System. Installation, Drilling, Production, and Workover from the Same Semi.

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DEVELOPMENT OPTIONS

Dry Trees Dry Trees Wet Trees TLP SPAR Floating Production Unit Semi-Submersible FPSO Dry Tree Unit Tender Assist Drilling MODU Drilled Permanent Platform Facilities FSO

DRILLING STORAGE &

EXPORT SUBSTRUCTURES Selection of potential development options Development Option Components Facilities Elements Development Option Strategies All Wet Tie-backs Wet & Dry Subsea Tiebacks Pipeline Option Identification – Building Blocks

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Hull Size Total Facility Payload Total Facility Payload Topside Weight

• Type, Amount Boosting • Workover Rig

• Wax Hydrate Management • Oil / Gas Production

Throughput • Dry or Wet Trees • Drilling or No Drilling • Drilling, Completions • Flow Assurance • Boosting • Intervention • Well Count • Well Location • Production Profile • Geometry • Connectivity • Export Riser Weight • Export Riser Size, Type • Integrated Oil Storage / Shuttle • Oil Pipeline • Production Riser Weight • Station Keeping Weight • Production Riser Size, Type • Station Keeping Type Roadmap for Establishing Size of Floating Platform Pipeline Infrastructure • Water Depth • Metocean Reservoir Reservoir Size (Recoverable Reserves) • Geology • Rock Properties • Depth Below M/L • Salt Layer Fluid Properties (P, V, etc.)

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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

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– Topsides • Production Facilities • Drilling Systems • Utilities • Accommodations & Helideck – Hull • Columns • Pontoons • Pontoon Extensions • Riser Porches – Mooring System • Tendon Porches • Tendons • Foundations TLP Components Topsides Pontoons Columns Tendons

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Proprietary TLP Designs and Technology Providers

MODEC DESIGN

SBM ATLANTIA DESIGNS

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Typical Functions of a TLP Functions Considered Full 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

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# 55 TLP Drilling & Production Configurations Tender assist drilling & production mode Platform drilling & production mode Wellhead platform mode with remote production

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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 FPSO SWHP

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# 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

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Typical TLP Tendon Make‐up

Connected to Tendon Porch

MWL+3937 ft

Pretension 2750 kips

TTS

TTS, TBS and MB1 to MB 14 ALL Approx. 240 ft long

1 2 3 4 5 Segments 1 to 14 Each Segment (240 ft) consists 60 ft pipes girth welded

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# 59 Stepped Tendon System Open Tendon Porch Closed Tendon Porch TLP Tendon Porches

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Free Standing Tendon Installation TTS Mud line TBS WD 1200 m (3937 ft) Main Pipe Water Surface Buoys Connected 100 ft from top of tendon Buoy Dimension: 18’ OD x 50 ft long

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TLP Riser Stack‐ups

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Typical Wellbay Layout (TLP Supported Risers)

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Hull Fabrication

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Hull Fabrication at Quayside

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Mars TLP

Ursa TLP ‐ Barge

Ram/Powell TLP Kizomba TLP

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Hull Float‐Off

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Deck/Hull Quayside Integration

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System Delivery

Deck Lift & Integration

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Deck Lift & Integration

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Deck Integration

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Platform Commissioning

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Platform Dry Transport

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# 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

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Spar Features Truss Hard Tank Topsides  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

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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

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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)

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# 99 Front Runner Devils Tower Medusa Geotechnical Considerations • Bathymetry (bottom contours, escarpments, etc.) • Geotechnical (hazards, soils, faults, etc.)

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Spar Mooring Systems MWL 8200'-0" R4 STUDLESS CHAIN 3 SEGMENTS POLYSTER ROPE

TRUSS SPAR PLATFORM

SCR (TYP.) SCR PORCHES R4 STUDLESS ANCHOR CHAIN SCR ( TTR 10°-14° (TYP.) MWL RQ4 STUDLESS CHAIN

SPIRAL STRAND STEEL WIRE

OR CHAIN

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

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# 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

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Riser System Options: Wet Trees Riser Hang‐off Porch:  Flexjoint  Stress Joint Pull Tubes:  Flexibles  SCR’s

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Riser System Options: Dry Trees

Buoyancy Can

Hydraulic Multi-riser Buoyancy Can

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Spar Buoyancy Can Tensioner (non‐Spar supported)

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Spar Ram Type Tensioners (Spar‐supported)

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Riser Options (Flexibility): Combination Dry & Wet Tree

Pull Tubes, SCR’S OR Flexibles

Dry Tree Riser Slots, Top Tensioned Buoynacy Cans

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# 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.

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Centerwell Arrangement ‐ Example Export Lines (2) Drain Sump Buoyancy Cans (8) Misc. Utilities Flowlines (10) Umbilicals (5)

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# 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

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Panel Line Ring Sections 1/8 Sections 1/4 Sections 1/2 Sections Full Sections Spar Hard Tank Build Philosophy

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# 111 Upper Half Ring Section Assembly Lower Half Ring Section Assembly Ring Section Mating H HT Half Ring Assembly and Mating Methodology

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First Cutting of Steel Center Bulkhead Assembly 1/8 Segment Assembly

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UPPER SECTION

BLOCK E BLOCK F

LOWER SECTION

BLOCK B BLOCK A BULKHEAD BLOCK G BLOCK H

BLOCK C BLOCK D BULKHEAD

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1 2 3

4 5 6

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Hull Upend Sequence

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Post Up‐end Stages

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Anchor Types Suction Piles Suction Piles 60 st 60 st ––250 st250 st Driven Piles Driven Piles 150 st 150 st ––230 st230 st Driven Piles Driven Piles 150 st 150 st ––230 st230 st Drag Anchors Drag Anchors 30 st 30 st ––50 st50 st

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Chain Jacks Set Work Deck

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Anchor Chain Hook‐up

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# 139 Spar Riser Installation Seafloor Stress‐Joint & Connector Casing Keel‐Joint Buoyancy Can

Tapered Stress & Cross Production Riser

Keel and Transition J Flowline Jumpers & Umbilicals Tieback Connector Stem Centralizers Buoyancy Can Surface Wellhead & Tree Subsea Wellhead

Tapered Stress & Cross Production Riser

Keel and Transition J Flowline Jumpers & Umbilicals Tieback Connector Stem Centralizers Buoyancy Can Surface Wellhead & Tree Subsea Wellhead

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Tapered Stress & Crossover Joints Production Riser

Keel and Transition Joints Flowline Jumpers & Umbilicals Tieback Connector Stem Centralizers Buoyancy Can Surface Wellhead & Tree Subsea Wellhead

Tapered Stress & Crossover Joints Production Riser

Keel and Transition Joints Flowline Jumpers & Umbilicals Tieback Connector Stem Centralizers Buoyancy Can Surface Wellhead & Tree Subsea Wellhead

Jumpers Can Installation Upper Stem

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# 143 Semi‐FPS Statistics • Operating : 39 • First: 1975, Argyll, Hamilton • Deepest: 7,920 ft, MC920 Independence Hub • Locations: Worldwide

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# 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

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# 147 Conventional Production Semi • Column extended for deep draft • Reduced column/pontoon size for better motion Deep Draft Semi Pre‐Katrina The Evolution of the Post‐Katrina Deep Draft Design Deep Draft Semi Post‐Katrina • Column extended for air gap • Increased column spacing for stability

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ATANTIA DEEP DRAFT DESIGN

AKER KVAERNER DEEP DRAFT DESIGN

GVA / KBR DESIGN

EXMAR DESIGN MOSS MARITIME _FLOATEC

Proprietary Semi‐FPS Designs and Technology Providers

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Semi‐FPS Hull Construction (Nodes Sub‐block Assembly)

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Semi‐FPS Hull Construction (Pontoon Sub‐block Assembly)

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Semi‐FPS Hull Construction (Erection of Nodes Sub‐block)

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Semi‐FPS hull Construction (Pontoon Erection)

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Semi‐FPS Hull Construction

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Semi‐FPS Hull Construction (Undocking of Pontoons)

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Semi‐FPS Hull Construction (Undocking of Pontoons)

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Semi‐FPS Hull Construction (Column Block Assembly)

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Semi‐FPS Hull Construction (Consolidating Column Blocks)

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Semi‐FPS Hull Construction (Erection of Column Blocks)

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# 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

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Semi‐FPS Topsides Integration (Mating Completed)

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Semi‐FPS Topsides Integration (Single Lift)

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# 175 FPSO Statistics First Deepest Operating 1977 Castellon, Shell 6,086 ft., Roncador 128 Worldwide Locations

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Ship‐shape FPSO Components

Hull

(Conversion or New Build)

Topsides

Turret and Mooring (Permanent or disconnect)

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FPSO Topsides Modules P1 P2 P3 P4 P5 P6 P7 P8 S1 S2 S3 S4 S5 S6 S7 S8 Main E&I Bldg Seawater Water Injection Seawater Filtration & Utilities HP & HHP Gas Power Generation Power Generation (3 trains) Seawater Deaeration Production Manifolds Oil Dehydration Future Module LP & MP Gas Compression Oil Offloading

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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

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The Next Generation FPSO • Combines the benefits of a MODU and a floating storage, production and offloading unit

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