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GE Confidential
Competitiveness of Deepwater
TechnologyRoundtable hosted by
International Energy Agency (IEA) Gas & Oil Technology
Collaboration Programme (GOT) and FINEP, Brazil
Rio Oil & Gas Expo, 27 Oct 2016
Supported by
GE Confidential
IEA Gas and Oil Technology Collaboration Programme- Next 10 years of subsea and deepwater(Numbers refer to subsequent slides)
1) The workshop in Rio 8-9 March this year convened major stakeholders to discuss common challenges and visions for the industry.
2) In a series of meetings and telecons, a work group has maintained focus and provided a basis for a joint industry effort towards an interim meeting during Rio Oil and Gas.
3) In the same timeframe, GOT held a workshop on Mature Fields in London where the need for disruptive innovation and Design to Cost was underscored.
4) The pre-salt development in Brazil offers a clear case for radical change: the first 10 major FID’s and CAPEX commitments were made in a $100 environment.
5) The work group discussed a «virtual» oilfield and gasfield to be used as a design basis for the Design to Cost exercise.
6) At $30/bbl oil price, a 300 mmbbl oilfield yields $9Bn gross revenue to cover costs over the lifetime. A design to cost approach could be to allow 50% for OPEX and the rest for CAPEX, to cover Wells, SPS+SURF, and Facilities.
7) From a technology viewpoint, the challenge is to pinpoint the gaps in solutions, systems, equipment, work processes and innovation chain, that stops the industry from cutting cost by 50%.
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«All Electric» is a key enabler that cuts across
most cost items of a deepwater field development
3
Where we left after the GOT Workshop,
Rio 8-9 March 2016
• How to sustain at 30$ oil
• (Shale oil will kick in)
• Cost out: 30-40% needed
• Standardization and work processes
only part of the solution
• Technology and new solutions needed
• Faster innovation chain
• Involve supply chain early
• How can we cooperate to meet the
challenge
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GE Confidential
GOT key actions - Conventionals
• Design to cost – Out-of-the-box solutions that make marginal field development feasible @ 30$
• Standardization – subsea, floaters, etc
• Drill & produce @ 3000m WD – New well control rule, reduce BOP weight and payload, all electric, composite risers
• Remote fields 300kms offshore – Subsea compression, subsea gas/CO2 separation and reinjection, all electric subsea to shore
• Robotic drilling, unmanned platforms
• Changing market landscape – newcomers taking over old fields (may need more help)
• The water issue. Enormous amounts of water to be handled
• Light subsea well intervention faster and cheaper
• Help operators build confidence in business cases for CAPEX decisions in late life
Greenfield Brownfield
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GE Confidential
Pre-salt field development- Santos, Campos, Espirito Santo
‘10 2011 2012 2013 2014 2015 2016
Lula Pilot – FPSO Cidade de Angra dos Reis Oct
Sapinhoá Pilot – FPSO Cidade de São Paulo Jan
Lula Nordeste Pilot – FPSO Cidade de Paraty Jun
Lula/Iracema Sul – FPSO Cd. de Mangaratiba Oct
Sapinhoá Norte – FPSO Cidade de Ilhabela Nov
Lula/Iracema Norte – FPSO Cidade de Itaguai Jul
Lula Alto – FPSO Cidade de Maricá Feb
Lula Central – FPSO Cidade de Saquarema Xxx
Lapa – FPSO Cidade de Caraguatatuba Xxx
Route 2 gas p/l (Santos – Cabiúnas Macaé) Feb
MODEC - conv. VLCC, lease, 5 SS P, 100,000
bbl/d oil, 5Mm3/d gas, H2S & CO2 removal, CO2 RI
MODEC - conv. VLCC, lease, 120,000 bbl/d
oil, 150,000 bbl/d total liquid
SBM - conv. VLCC, lease, 150,000 bbl/d
total liquid, 5Mm3/d gas
SBM – newbuild at Brasa, Ilhabela blueprint,
lease, 150,000 bbl/d oil, 5Mm3/d gas
SBM – newbuild at Brasa, lease,
150,000 bbl/d oil, 5Mm3/d gas
SBM – newbuild at Brasa, lease,
150,000 bbl/d oil, 5Mm3/d gas
MODEC - conv. VLCC,
lease, 150,000 bbl/d oil
MODEC - conv. VLCC,
lease, 150,000 bbl/d oil
MODEC – EPCI+T/C,
lease, 100,000 bbl/d oil
80bn boetotal potential
reserves
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GE Confidential
Pre-salt characteristics – Virtual oilfieldReservoir depth: > Heterogeneous carbonates, 4-6km below
seabed
Under layers of rock and salt (2000m or more)
Challenges
• Seismic imaging, interpretation, reservoir characterization
• Borehole stability in salt zone
• Temperature gradient along flowpath
Cost per well – US$ 100-150m or more
Tupi may require 200 wells
Total development cost (CAPEX+OPEX) of Tupi ~US$600bn over lifetime
“Virtual Field”:
The functional specifications and overall description should include
Field size (recoverable reserves – 100-200-300 Million bbls?)
Water depth (3000m?)
Distance to shore (300 km?) Distance to infrastructure?
Metocean conditions
Reservoir depth
Gas or oil field? GOR
Number of wells (Production, Injection)
Recovery method (depletion, pressure maintenance, WI, WAG, …)
H2S content, CO2 content, …
The work group should define a set of imaginary field
developments that pose real challenges to the oil & gas
community –
• 300 mmbbl oil field, stand-alone development
• 100 mmbbl oil field(s), long tieback to hubs or S2B
• (Major) gas field, subsea to beach (S2B)
• Gas field, subsea power to beach (P2B)
3000 m waterdepth, 300 km from shore, $30 breakeven
5
GE ConfidentialCost Out – Where? How? Who?
Drilling & Wells
Facilities
Subsea & Flowlines
Subsea processing
Standard X-trees
Interface std’s
All Electric
Simpler
Lighter
No downtime
Higher ROP
Robotics
Automated Drilling
Monobore wells
Standard completions
Standard FPU/FPSO
Robust design
Multi-use, Re-use
Reduce waste – Water, CO2, H2S
MMBoe
BUSD gross CAPEX DW SF FP OPEX
SW 75
DW 150
UDW 300 9 4,5 1,5 1,5 1,5 4,5
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All electric
AE
otherdisruptive
+ innovations
Design to Cost: 3000m wd, 300 km, 300 mmbbl, $30 b/e
AE BOP: remove hydraulics, accum.bottles, failure modes. Enable Real Time monitoring. Weight ↓ 50%
Less BOP weight -> reduced risers and deck load enablinglighter drilling vessels -> Rig rates ↓ 50%
AE Robotic drilling: Higher efficiency, reduced downtime, reduced offshore manning, cost ↓ 50%
Hydraulic 700 t
All Electric 350 t
Wikipedia: A disruptive innovation is an innovation that creates a new market and value network and eventually disrupts an existing market and value network, displacing established market leading firms, products and alliances.
Subsea Production System
AE SPS: El actuators, remove hydraulics, add boosting & compression, eliminate umbilicals – Cost ↓ 50%
Standard Subsea XT Bulk water
separation and disposal, CO2/H2S handling at source, Cost ↓ 50%
Standard FPSOStandard ProcessCost ↓ 50% -
Or eliminate completely!
Cold Flow -
Cold Flow processing to pipeline spec, hydrate /wax/ corrosion control, single pipeline to shore or hub – Cost ↓ 50%
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