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MCE Deepwater Development 2016
PAU, FRANCE • 5-7 APRIL 2016
All Electric Subsea Production System – A World First
Rory MacKenzie Total E&P, Technology Division
Key Contributors:
Cedric Roux – Total E&P Netherlands BV, K5-F3 Project Manager
Antonin Baume – Total E&P, Drilling and Wells Division
Ewan Allstaff – Total E&P, Drilling and Wells Division
Juliano Pimentel – Total E&P, Deep Offshore R&D Division
MCE Deepwater Development 2016
K5-F Development
MCE Deepwater Development 2016
K5F All Electric Xtree
MCE Deepwater Development 2016
K5-F Status Overview • Development launched in 2005
• AET manufacture and test completed 2008
• Phase 1 deployed in May 2008
• Hydraulic SCSSV
• Actuator reliability – 100% to date
• Power distribution/Hydraulic system failures experienced
• Phase 2 development launched in Nov. 2013
• Business driven decision to include electrical SCSSV to
address hydraulic leak issues July 2014
• Qualified improved system design 2015
• Completed manufacture and test Jan 2016
• Deployment due May 2016
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Halliburton electrical SCSSV (eDHSV)
Based on DepthstarTM technology • Field proven (in operation since 2006) – no operational issues • Magnetically coupled SCSSV – tubing integrity maintained • 100 % MTM – no moving seals within the tubing wellbore • eDHSV Fully Qualified to ISO/API and extended HALT/ALT testing
• Dual electric linear actuators • Electronics isolated from well fluids and pressure • Position sensor – real time status • Full redundancy in actuation and controls
Features
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Incorporating the eSCSSV into K5F-3 • Hydraulic SCSSV included as backup (project acceptance)
• 2 retrievable A&B channel control units fitted to Xtree
• Industry standard interface to SCM (low power IWIS)
• Contains interface cards, PSU and ESD power storage
• 2 additional electrical feedthroughs/cables included
• Standard downhole gauge components
• Completion design modified to accept electrical SCSSV
• Project specific lock-out tool developed
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AE System – Key Benefits HSE
• Removal of hydraulic fluid • Supply, transportation, storage • Spillage, contamination
• Removal of high pressure storage
CAPEX • Removal of topside hydraulic infrastructure • Removal of hydraulic lines in umbilicals (>> long stepouts) • Removal of subsea hydraulic distribution system • Removal of hydraulic tubing on Xtree’s and Manifolds (<-20%) (cutting, bending, welding, fitting, flushing, testing etc)
Functionality • Control, Speed, Feedback, Condition Monitoring, Self Test • Hybrid options – eDHSV and/or eChoke on conventional EH systems • Ultra deep water, ultra long offset, subsea processing
Reliability • Technology transfer - quantifiable MTBF figures, 15 years subsea • Built-in redundancy all the way to the valve
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Case Study – AE/EH long offset Umbilicals 6 well template, 10 valves/well 30 years operation, 3 act/valve/year Umbilical - 4 x ¾” lines, 2 x FO tubes, 2 x quads/triads
Hydraulic fluid and electrical power consumption (100Mw GTG) 50%-65% cost saving for AE
0
20
40
60
80
100
DC AC 16.7Hz AC 50Hz
AC 16.7Hz 3Ø AC 50Hz 3Ø
31.6 31.6 39.2 31.6 31.6
86.7 86.7 86.7 90.0 90.0
CAPE
X (M
illio
n $)
CAPEX – 175km
All Electric
Electrohydraulic
0
100
200
300
400
DC AC 16.7Hz AC 50Hz
AC 16.7Hz 3Ø AC 50Hz 3Ø
121.0 163.2
302.4 316.8 342.7 321.8 346.0
CAPE
X (M
illio
n $)
CAPEX – 600km
All Electric
Electrohydraulic 0
50
100
DC AC 16.7Hz AC 50Hz
AC 16.7Hz 3Ø AC 50Hz
3Ø
32.4 40.9 62.8
40.9 51.8
87.3 87.5 87.9 90.8 91.2
COST
(Mill
ion
$)
Total Cost : 175km Offset
All Electric
Electrohydraulic
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Conclusion - Long Offset concept (OIL)
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Conclusion - Long Offset concept (Gas)