modus as mopus: low cost field development · •subsea tree - mopu motions do not allow for dry...
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MODUs as MOPUs: Low cost field development
using hybrid risers
Pedro Viana
2H Offshore
Learn more at www.2hoffshore.com
2
Contents
• Objectives
• Background
• Typical Arrangements for FPU / Riser
• Free Standing Hybrid Risers – key aspects
• Proposed Alternative(s)
• MODU as FPU: Drilling & Completion, Production & Installation
• Historical Precedence & Current Scenario
• Comparison: Converted MODU vs. TLP
• Installation Method
• Conclusions & Closing Remarks
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3
Objectives
• Describe how the conversion of Mobile Offshore Drilling Unit (MODU) into a Floating Production Unit (FPU), keeping drilling and adding installation capabilities, can be a complete and cost effective solution when considered in association with a Free Standing Hybrid Riser (FSHR).
• Present how previous industry experience and current market conditions turns it into an timelly opportunity.
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5
Background Typ. Arrangements for Floating Production Unit and Risers (and 2H areas of expertise)
Rigid & Flexible Risers
Risers & Well Conductors Engineering
Hybrid Risers
Top Tensioned Risers
Drilling Risers
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6
• Not highly sensitive to environmental loading or FPU motions
• Low payload on platform and moorings
• Large diameters; “any” water depth
• Pre-Installable • decouples installation from FPU and flowlines schedule
• Flow assurance flexibility • Large insulation thicknesses
• Pipe-in-Pipe
• CRA lined pipe
• Opportunities for Local Content (Africa, Brazil)
• Unique seabed contact point
• Lower installation cost by installing from the MODU • $60MM to $25MM per installed riser
Background Free Standing Hybrid Risers (FSHR) – key aspects
Buoyancy Tank
Tether
Upper Riser Assembly (URA)
Standard Riser Joints
Base Jumper
Foundation
Flexible Jumper
To FPU
Lower Riser Assembly (LRA)
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8
Proposed Alternative Options
• Option A: MODU re-purposed as FPU only
• Minimal or full processing facility
• Fluid processed at MODU before export
• Future drilling & intervention by a different MODU
• Option B: MODU repurposed as FPU + drilling & workover + FSHR installation
• Drill initial or future wells
• Install production risers - avoid costly heavy lift installation vessel
• Production fluids offloaded to FPSO
• Workover & intervene - maximize reservoir recoverability
• Permanent installation over field life – new requirements
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9
Proposed Alternative
Drilling & Completion, Production & Installation - OVERVIEW
Flex Jumper
Free Standing Hybrid Riser(s) (FSHR)
Transfer System (s) (mid water or FSHR-flowline-Riser)
FPSO
Mooring
Subsea Tree
Subsea Umbilical
Drilling Riser
Mooring
Flowline
Manifold
Converted Semi-Sub: • Drilling • Production • Installation
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Proposed Alternative Field Layout Arrangement Rationale
• Constraints Accommodated:
• Subsea Tree - MOPU motions do not allow for dry tree Top Tensioned Risers
• FSHR – minimizes riser load even in deepwater
• Production transfer to FPSO - minimizes additional payload and deck space and allows the drilling rig to be maintained
• Subsea trees located under drilling vessel to enable through life drilling/workover access
• Offloads to leased FPSO providing overall low CAPEX solution
• Improved and alternate from TLP-FPSO Solution (W Africa, SE Asia and Brazil)
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Proposed Alternative Applications & Additional Benefits
• Particular value for:
• Fields that would otherwise need a substantial production and drilling host (PDQ)
• Marginal fields
• Early production / extended well test.
• But valuable for any (applicable) field:
• Long lead-time and expensive TLP/FPU can be avoided.
• Heavy construction vessel can be avoided
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13
Historical Precedence FSHR’s to Date
Type Field Status Owner/Field
Operator Yr. Installed Region
Water Depth Vessel
(ft) (m)
Bu
nd
le
Green Canyon 29
Garden Banks 388
De-commissioned
Placid Oil Comp/
Ensearch 1988/1994 GoM 1,529/2,096 466/639 Semi-Submersible
Girassol Operating Total Elf 2001 Angola 4,430 1,350 Spread Moored FPSO
Rosa Operating Total Elf 2007 Angola 4,430 1,350 Spread Moored FPSO
BP Greater Plutonio Operating BP 2007 Angola 4,300 1,311 Spread Moored FPSO
Sin
gle
Lin
e
Kizomba A & B Operating Exxon 2004/2005 Angola 3,330-4,200 1,006 to 1,280
Spread Moored FPSO
Block 31 / PSVM Operating BP 2012 Angola 6,890 2,100 Turret Moored FPSO
P-52 Operating Petrobras 2007 Campos Basin
5,906 1,800 Semi-Submersible
Macondo De-commissioned
BP 2010 GoM 5,000 1,515 DP FPSO
Cascade/
Chinook Operating Petrobras 2010 GoM 8,531 2,600 Turret Moored FPSO
Block17/ CLOV Operating Total 2014 Angola 3,600-4,600 1,100-1,400 Spread Moored FPSO
Block32/ Kaombo Construction Total TBC Angola 4,675-6,315 1,425-1,925 Turret Moored FPSO
Note: bold indicates 2H involvement in FEED or Detailed Design Learn more at www.2hoffshore.com
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Historical Precedence MODU Conversions to FPU
• 15 conversions were carried out in last major oil downturn between 1986-1999
• Mostly semi-submersibles
• Typical water depths < 1,000m
• Subsea developments using flexible risers
Ref: Deegan, Loffman, Odufuwa, “The conversion of Mobile Offshore Drilling Units to Floating Production System – Issues, Opportunities and Challenges”, DOT 2014
Vessel Field Startup Region Water Depth (m)
Argyll FPU Argyll Oil Field 1975 UK North Sea 150
Buchan A Buchan oil field 1981 UK North Sea 160
P-09 Corvina Oil Field 1983 Brazil 230
P-15 Pirauna 1983 Brazil 243
P-12 Linguado / Badejo Oil
Field 1984 Brazil 100
P-21 Badejo / Salema Oil
Fields 1984 Brazil 112
Deepsea Pioneer FPU Argyll & Duncan Oil
Fields 1984 UK North Sea 150
P-22 Morela 1986 Brazil 114
P-07 Bicudo Oil Field 1988 Brazil 207
Veslefrikk B Veslefrikk Oil Field 1989 Norwegian Sea 175
AH001 Ivan Hoe Rob Roy Oil
Field 1989 UK North Sea 140
P-20 Marlim 1992 Brazil 625
P-08 Marimba Oil Field 1993 Brazil 423
P-13 Bijupira / Salema Oil
Field 1993 Brazil 625
P-14 Coral / Esrela /
Caravela Oil Fields 1993 Brazil 195
Nan Hai Tiao Zhan Luihua 1995 South China Sea 300
P-25 Albacora II Oil Field 1996 Brazil 252
P-27 Voador 1996 Brazil 533
Tahara PY-3 1997 Indian Ocean 339
P-19 Marlim 1997 Brazil 770
Janice A Janice Oil Field 1999 UK North Sea 80
P-36 Roncador 2000 Brazil 1360
SS-11 Coral 2003 Brazil 145
P-40 Marlim Sul 2004 Brazil 1080
ATP Innovator Gomez Oil Field 2006 Gulf of Mexico 914
Northern Producer
FPF
Originally Galley Oil
Field now at Don Oil
Field
2009 UK North Sea 350Learn more at www.2hoffshore.com
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Historical Precedence - Case Example Liuhua Field Development – Production and Drilling
Background:
• 300m water depth, South China Sea
• Marginal field, low recovery, high water cut
• Extend well tests
• Adjustable drilling & intervention requirements
Solution:
• Converted MODU: production and drilling capability
• Converted FPSO
• On seabed transfer – from manifold to FPSO
• Solution made development economically viable
Ref: Hall, Sheng, Krenek, Douglas, Macfarlane, “Liuhua 11-1 Development – Subsea Production System Overview”, OTC 1996, Paper 8175
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Current Scenario Worldwide Rig Count (Ref: HIS, Q3 2015)
• Opportunity for using idle low cost drilling vessel instead of new build TLWP w/ drilling rig
• Take advantage of current overcapacity in the drilling vessel market Learn more at www.2hoffshore.com
18
Converted MODU vs. TLP/TLWP Key MODU Advantages over TLP or Spar
• CAPEX - saving of up to 50% vs. TLWP/Spar
• Schedule - first oil anticipated by one year or more
• RISKEX - lower installation risk compared with TLP and Spar installations
• Maintain life of field workover capability for maximum reservoir recoverability
• Manage reservoir uncertainty
• Maximum end of life well count is not a driver for drilling vessel selection - flexibility
• Can also be an early production system
• Subsea architecture is organically expandable using the drilling vessel and a support vessel (MSV) to install more trees, risers, flowlines and jumpers
• Vessel and riser system can be readily retrieved and relocated
Learn more at www.2hoffshore.com
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Converted MODU vs. TLP/TLWP Key MODU Advantages over TLP/Spar
• Schedule - first oil anticipated by one year or more
• CAPEX - saving of up to 50% vs. TLWP/Spar
• RISKEX - lower installation risk compared with TLP and Spar installations
• Maintain life of field workover capability for maximum reservoir recoverability
• Manage reservoir uncertainty
• Maximum end of life well count is not a driver for drilling vessel selection - flexibility
• Can also be an early production system
• Subsea architecture is organically expandable using the drilling vessel and a support vessel (MSV) to install more trees, risers, flowlines and jumpers
• Vessel and riser system can be readily retrieved and relocated
Learn more at www.2hoffshore.com
20
Converted MODU vs. TLP/TLWP Schedule Comparison
1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q
X
X
X
FSHR Installation (1 off)
Install flexibles and umbilicals (w flex
lay vessel)First oil (with 3 wells)
1st Batch 3 off Subsea Trees Delivery
(w manifold, well jumpers and 1st Batch 1 off Riser Delivery (w
surface and seabed jumpers)Mooring Pre Installation
Semi Installation
Drilling and completion from Semi (3
wells)
Integrated Rig With TLP
FEED
Sanction & Detailed Design
Puchase semi and conversion (w
permanent moorings)
Semi-submersible with FSHR
Tendon Installation
TLP Installation & Commissioning
(Ready to drill or complete)First completion and first oil (1 well)
Producing (3 wells)
MODU Drilling (Batch set conductors
and drill 4 wells)
FEED - 20 Slot TLP
Sanction & Detailed Design
TLP Construction & Integration
TLP Tendon Fabircation
1st Batch Riser Delivery (3 production
and 1 drilling)
Year 1 Year 2 Year 3 Year 4 Year 5
1st oil reduction over 1 year
Integrated Rig with TLP
Semi-Sub with FSHR
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Converted MODU vs. TLP/TLWP CAPEX Comparison
USD ~ 1.4 MM USD ~ 0.4 MM
$1,377,250,000
Integrated Rig With TLP
TLP Installation & Commissioning
(Ready to drill or complete)
First completion and first oil (1 well)
Producing (3 wells)
MODU Drilling
(Batch set conductors and drill 4 wells)
FEED - 20 Slot TLP
Sanction & Detailed Design
TLP Construction & Integration
TLP Tendon Fabircation
1st Batch Riser Delivery
(3 production and 1 drilling)
Tendon Installation
$90,000,000
$1,000,000,000
$90,000,000
$40,000,000
$25,000,000
$39,000,000
-
-
$93,250,000
Total $417,250,000Total
Mooring Pre Installation
Semi Installation
Drilling and completion from Semi (3 wells)
FSHR Installation (1 off)
Install flexibles and umbilicals
(w flex lay vessel)
First oil (with 3 wells)
FEED
-
-
$35,000,000
$290,000,000
$35,500,000
Semi-submersible with FSHR
Sanction & Detailed Design
Puchase semi and conversion
(w permanent moorings)1st Batch 3 off Subsea Trees Delivery
(w manifold, well jumpers and umbilical)1st Batch 1 off Riser Delivery
(w surface and seabed jumpers)$25,000,000
$5,250,000
$6,500,000
-
$12,500,000
$7,500,000
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23
Installation Method (key steps) Field Proven
Foundation installed Aircan brought to moonpool
Vertical riser run w/ LRA attached (at bottom) URA connected (at top)
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24
Installation Method (key steps) Field Proven
Aircan connected to top of URA, lowered into water and ballasted
LRA landed and latched Aircan deballasted
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25
Installation Method (key steps) Field Proven
Vertical riser free-standing
Light construction vessel pays out flexible jumper ROV attaches A&R wire and connects jumper to URA
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27
Conclusions & Closing Remarks
MODUs as MOPUs: Low cost field development using hybrid risers
• Solution achievable with a combination of field proven technical solutions
• Surplus rigs in the drilling market is an additional opportunity to reduce CAPEX by up to 50% and time to 1st Oil by 1 year compared to an equivalent TLWP
• Subsea trees and freestanding risers enable a MODU to be repurposed as a permanent moored drilling and workover vessel for deepwater
• Arrangement provides expansion flexibility to minimize upfront CAPEX and protect against reservoir uncertainty
• Risers and vessels can be retrieved and relocated
Learn more at www.2hoffshore.com
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Questions?
Thank you for your attention
Obrigado!
Pedro Viana | Technical Manager | 2H Offshore +44 1483 775027 Pedro.Viana@2hoffshore.com
Learn more at www.2hoffshore.com
30
Proposed Alternative
Drilling & Completion, Production & Installation - OVERVIEW
Flex Jumper
Free Standing Hybrid Riser(s) (FSHR)
Transfer System (s) (mid water or FSHR-flowline-Riser)
FPSO
Mooring
Subsea Tree
Subsea Umbilical
Drilling Riser
Mooring
Flowline
Manifold
Converted Semi-Sub: • Drilling • Production • Installation
Learn more at www.2hoffshore.com
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