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MCE Deepwater Development 2016
PAU, FRANCE • 5‐7 APRIL 2016
Setting new records with subsea boosting systems in fields in the Gulf of Mexico, North Sea, and offshore Angola
Arne B. Olsen
MCE Deepwater Development 2016
Content
Introduction Historic view of boosting Record breaking fields
Jack & St Malo Gullfaks GirRI
Why select boosting as artificial lift
MCE Deepwater Development 2016
Historic View
MCE Deepwater Development 2016
Subsea booster pumps – differential pressure
1990 2000 201020051995
20406080
100120140160180200220240260280300
Year0
bar
2015
1997, Lufeng, 35 bar1997, Lufeng, 35 bar2003, Ceiba, 40 bar2003, Ceiba, 40 bar
2009, Pazflor, 105 bar2009, Pazflor, 105 bar2014, GirRI, 130 bar2014, GirRI, 130 bar
2018, Stones, 290 bar2018, Stones, 290 bar
2008, Azurite, 41 bar2008, Azurite, 41 bar
Multiphase PumpMultiphase Pump
Single phase PumpSingle phase Pump
MCE Deepwater Development 2016
Subsea booster pumps – shaft power
1990 2000 201020051995
200400600800
10001200140016001800200022002400260028003000
1997, Lufeng1997, Lufeng
1999, Troll1999, Troll2007, Tordis2007, Tordis
2013, JSM2013, JSM
2010, GSC2010, GSC
2009, Pazflor2009, Pazflor
2006, Colomba E2006, Colomba E
1999, Topacio1999, Topacio
02015
2014, Shell TQP2014, Shell TQP
32003400360038004000
Year
MCE Deepwater Development 2016
PAU, FRANCE • 5‐7 APRIL 2016
Fields
MCE Deepwater Development 2016
Chevron ‐ Jack & St Malo, Gulf of Mexico
2400 m Water Depth, 13.000 psi design pressure
Production enhancement
Stage 1: Single phase boosting
Stage 2: Multiphase + single phase boosting
Chevron expectation: 50 – 150 mbo increase by boosting
MCE Deepwater Development 2016
Key data: 60,000 bbld 3 MW shaft power 4,000 psi/280 bar boost 22 km tie-back
Jack & St Malo pump stations
MCE Deepwater Development 2016
Installed and commissioned
MCE Deepwater Development 2016
OneSubsea multiphase compressor technology has been developed over the last 25 years.
All subsea components are based on an unparalleled experience of more than 2,5 mill. accumulated operational hours of subsea pumps.
Main Features:
Contra‐rotating impeller shafts
Multiple stages without diffusers
Surge‐free blade design
Integrated flow mixing
Field‐proven motor, seals, and bearing technologies
• Development and qualification of OneSubsea’s multiphase compressor technology was carried out in close cooperation with major operators, such as Statoil and Shell.
Upper motor(drives outer impeller rotor)
Compressorw/integrated flow mixer
Lower motor(drives inner impeller rotor)
OneSubsea® multiphase compressor system
MCE Deepwater Development 2016
Gullfaks multiphase compression system –Installed 2015 ‐ worlds first
2 off Cooler Modules
UTA
Protection structure
2 off Compressor Modules
2 off Subsea Control Module
Compressor Station
Leakage Detector
MCE Deepwater Development 2016
Compressor station installation
Power 10 MW Shaft total power Controlled from Gullfaks A
Flowrate 6000 Am3/h = 406
MMScft/d) Mix of gas and liquid
Pressure increase from inlet to outlet Up to 32 bar per
compressor, 64 bar in series
MCE Deepwater Development 2016
Existing Girassol FPSO
Existing Dalia FPSO
New MPP station P80 Rosa production loop
New MPP station P70 Rosa production loop
Pump Control module + IPC transformer (Power sharing between FPSOs)
IPC transformer (Power sharing between FPSOs)
Illustration; Courtesy by Total
GirRI ‐ a bold multiphase pumping project
MCE Deepwater Development 2016
PCM
GirRI pump system
Scope 2 dual pump stations 2 suction anchors (manuf. in Angola) 6‐off subsea high boost pumps Topside power and control module
Challenge 15 and 7 km tie‐back (P80 and P70) 1400 m water depth 130 bar differential pressure
MCE Deepwater Development 2016
GirRI pump system ‐ Testing
MCE Deepwater Development 2016
GirRI P70 pump system in operation
“These pumps allow recovery of about 42mn barrels of additional reserves.”Sonangol said in a statement (ref: Reuters).
MCE Deepwater Development 2016
PAU, FRANCE • 5‐7 APRIL 2016
Why select boosting for Artificial Lift
MCE Deepwater Development 2016
Typical AL screening study
0
10 000
20 000
30 000
40 000
50 000
60 000
2020 2025 2030 2035 2040 2045
Daily Produ
ction (BBLS/d)
Daily Production
Nat10" RBGL10"
MPP8" MPP10"
‐5 000
0
5 000
10 000
15 000
2020 2022 2024 2026 2028 2030 2032 2034 2036 2038 2040
(BBLS/d)
Additional Daily Production wrt RBGL10"
Nat10" RBGL10"
MPP8" MPP10"
‐200
0
200
400
600
800
1000
2020 2025 2030 2035 2040 2045
Accumulated
Disc
ounted
Cash Flow
pr. Year
(MMUSD
)
Payback, Incr. DCF wrt RBGL10"
Nat10" RBGL10"
MPP8" MPP10"
MCE Deepwater Development 2016
«Promissing technology for 25 years...»
Boosting adds energy Increases flow/recovery rates (30 – 100% +) Large differential pressures (200 bar) Maintain plateau production Enabling technology Allows smaller ID pipelines Improves flow assurance Tie‐backs 100 to 150 km available today 3000 m water depth Fully qualified technology (20 years experience) What more does it take?
