subsea separation – an undervalued tool for increased oil
TRANSCRIPT
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MCE Deepwater Development 2016
PAU, FRANCE • 5‐7 APRIL 2016
Subsea separation – an undervalued tool for Increased Oil Recovery (IOR)
Lachlan McKenzieFMC Technologies
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MCE Deepwater Development 2016
Subsea separation in the market• Subsea separation established globally. Projects installed:
‐ Africa‐ North Sea‐ Gulf of Mexico‐ Brazil
• Track record and results to point to‐ Proven, low risk technology available
• However… current market focus is on well stream boosting‐ Increasing number of (boosting) technology suppliers‐ Increasing choice of (boosting) technology‐ Thin separation prospect list
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MCE Deepwater Development 2016
Subsea separation – The track record
Tordis (2007)
Marlim (2009)
Pazflor (2008)
Perdido (2007)
Troll Pilot (1998)
Parque das Conchas (2006)
Proven Track Record:‐ Global Presence
‐ Africa‐ North Sea‐ Gulf of Mexico‐ Brazil
‐ Separation‐ Gas/Liquid‐ Liquid/Liquid
‐ Value adding: ‐ De‐bottlenecking‐ Enabling production‐ Increasing production
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MCE Deepwater Development 2016
Subsea separation – More than boosting• Flow assurance
• Hydrate management strategy• Slugging prevention
• Handling uncertainties in production profiles
• Enabling long distance transport
• Enabling deep water developments
• Maximising boosting effectiveness
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MCE Deepwater Development 2016
Subsea separation – Enabling boosting
Required Operation Point
New Operation Point
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MCE Deepwater Development 2016
Subsea separation – Case studies• Case Study 1
• Green oil field• 1000 m water depth• Harsh weather environment• Potential water breakthrough• Potential gas cap• High degree of uncertainty
Challenge: Minimize topsides. Maximize NPV.
• Case Study 2• Brown gas field• 900 m water depth• Subsea to beach• Declining reservoir pressure• Limited weather window for SURF scope
Challenge: Maximize Recovery.
Maximize NPV.
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MCE Deepwater Development 2016
Subsea separation – Case 1, Green oil field• How to maximize NPV?
INCREASE RECOVERY
TOPSIDE FACILITIES
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MCE Deepwater Development 2016
Subsea separation – Case study 1Solution 1: Water separation and disposal via proven technology
• Oil and gas free‐flow to surface• Water injected to disposal well
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MCE Deepwater Development 2016
Subsea separation – Case study 1Subsea Separation Solution 1
• Maximize recovery• Increasing recovery rate (enables lower WHFP)• Pressure support (if injected into production reservoir)
• Minimize topsides• Reduced first stage separator• Reduced water treatment
• Technical feasibility• Field proven technology• Feasible flow assurance
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MCE Deepwater Development 2016
Subsea separation – Case study 1Solution 2: Enable long distance transport
• Gas/Liquid separator• Liquid boosting, Gas free‐flow to off‐site facilities
• ‘Game changing’• No local receiving facilities, opens for many new development options
From wells
Liquid line
Gas line
LT
dP
Gas line
1
2
46
75
3
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MCE Deepwater Development 2016
Subsea separation – Case study 1Subsea Separation Solution 2
• Maximize recovery• Increasing recovery rate (enables boosting)• Maximizes uptime
• Minimize topsides• Eliminates on‐site FPSO• Enables use of existing facilities or dedicated facilities in shallower water
• Technical feasibility• Field proven technology• Feasible flow assurance
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MCE Deepwater Development 2016
Subsea separation – Case study 2• Case Study 2
• Brown gas field• 900 m water depth• Subsea to beach• Declining reservoir pressure• Limited weather window for SURF scope
Challenge: Maximise Recovery.
Maximize NPV.
Solution: • Distributed cooling and gas/liquid separation
• Liquid boosting
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MCE Deepwater Development 2016
Subsea separation – Case 2 study4 Processing stations:‐ Gas pre‐cooling‐ Gas/liquid separation
Gas freeflow to shore
1 liquid boosting station
Liquid boosted to shore
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MCE Deepwater Development 2016
Subsea separation – Case study 2Distributed gas/liquid cooling and separation:
Four off
Scrubber
TT
LT LC
PT
From Template
To Export Line
To Subsea Pump Station
Cooler
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MCE Deepwater Development 2016
Subsea separation – Case study 2Pump Station:
One off
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MCE Deepwater Development 2016
Subsea separation – Case study 2• Maximize recovery
• Avoid liquid accumulation – lower pipeline dP• Eliminate slugging• Enable liquid boosting
• Minimize expenditure• No need for new floating facilities• Distributed solution developed with a focus on minimizing SURF scope• Maximize use of existing field infrastructure• Enables phased deployment to maximise NPV
• Technical feasibility• Qualified separation technology
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MCE Deepwater Development 2016
Subsea separation – Case studies summary• Subsea Separation does things boosting alone cannot do
• Green field, Brown field, Gas, Oil…• Flow assurance benefits
• Slugging• Hydrate• Enables long distance transfer
• Enables use of single phase pump• More efficient pumping• More robust system: BoD, Transient conditions
• Enables increased recovery• Lower WHFP
• Topside equipment reduction• Minimize, eliminate or maximize use
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MCE Deepwater Development 2016
Subsea separation as an IOR tool – Summary• Proven, reliable, ready!
• And yet, undervalued…
• Subsea Separation (combined with boosting) unlocks value• To see the true potential the entire system must be evaluated• Must be included when considering field development options ‐ the bigger picture might be a brighter picture
• Game changing… if we let it!
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MCE Deepwater Development 2016
Subsea separation – an undervalued tool for Increased Oil Recovery (IOR)
Lachlan McKenzieFMC Technologies