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)