Subsea technology & potential significance to the UK TEPUK Subsea Europe 30/10/08
Top 18 Operators Top 18 Operators responsible for 74% of subsea trees 2,927 Subsea Trees 439 Projects TOTAL 2 - TEPUK Subsea Europe 30/10/08 Source:Quest Subsea Forecast Awards August2008
Total subsea assets Mid 2008 Gulf of Mexico Matterhorn (inj( inj) Chinook Tahiti UK Nigeria Akpo Usan Ellon Grant Nuggets Otter Forvie Jura Kessog Laggan / Tormore Egina - Preowei Bonga NORWAY Skyrne byggve Hild Victoria Snohvit Tordis Aasgard Tyrihans Netherland L4G K5F 37% of operated production RUSSIA Shtokman Flowing Under Construction Under study Major non op. Brazil Xerelete Argentine Argo 3 - TEPUK Subsea Europe 30/10/08 CONGO Moho Bilondo Moho North MTPS ANGOLA Girassol Dalia Rosa Pazflor CLOV Bloc 32 Bloc 31 Australia Ichthys 400 subsea wells operating from 2015
TOTAL Subsea Projects Track Records 2500 2000 Water Depth (m) 1500 1000 500 North Sea West Africa Golf of Mexico 10 Wells 0 1960 1970 1980 1990 2000 2010 Years Note : Bubble size represents the number of subsea wells 4 - TEPUK Subsea Europe 30/10/08
Numerous technological challenges Deep Water Long tie backs Complex fluids (Viscous, heavy, low energy) Smaller reservoirs Environment (metoecan conditions, protection) Industry cost current trend New architectural concepts Extended tie-back for paraffinic and none paraffinic fluids Subsea boosting up to 200 bars Subsea processing : decanter well, subsea water treatment and injection All electric technology : K5F AET pilot start-up, Electrical DHSV development Innovative materials : insulation, composite Subsea «autonomous» vehicles 5 - TEPUK Subsea Europe 30/10/08 Subsea gas compression
The challenge of deep water - Girassol Angola A challenging Flower Block 17, Angola Deepest and largest subsea development at Project Sanction in July 1998 Production capacity 240,000 bopd Riser Towers FPSO : 2 Mbls storage, 23,900t topsides 39 wells and 11 manifolds First use of Riser Towers (3 off) Extensive qualification program Startup December 2001 Girassol has opened new perspectives to the Subsea Technology 6 - TEPUK Subsea Europe 30/10/08
7 - TEPUK Subsea Europe 30/10/08 The challenge of deep water DALIA ANGOLA Integrated Production Bundles
The challenge of subsea processing and boosting Paz Flor Angola Project Sanctioned in Jan. 2008 Production capacity 230,000 bopd FPSO : 2 Mbls storage, 34,000t topsides 49 wells and 3 manifolds 3 Subsea Separation Units with multiphase booster pumps Startup in 2011 Why Subsea Separation Effective solution to manage flow assurance issues with the Miocene Heavy Oil 8 - TEPUK Subsea Europe 30/10/08
The challenge of long tie backs - Canyon Express ( Gulf of Mexico ) Water depth world record in year 2002 with 2,225 meters 100km tie-back from 3 fields Capacity : 500 MMCFD (14 MMSm /d) 2 x 12 looped flowlines, 9 wells Multiphase flow Intelligent well completions Start-up September 2002 King s Peak (BP) 2,000m / 3 wells Main um bilical Cam den Hills (Marathon) 2,225m / 2 wells 12-inch flow line Subsea tree 9 - TEPUK Subsea Europe 30/10/08 Methanol line Electro-hydraulic distribution unit Aconcagua (Total) 2,170m / 4 wells
Step Change All electric trees K5F Netherland First Subsea development with DC electric Xmas Trees Production Capacity 2MMsmd 2 wells 10 km subsea tie back to K6N Plaftform Water depth 40m Extensive qualification program First Gas in September 2008 Stimulus for all Electric Subsea Technology Step change improvement in reliability & availability Address limitations of electro-hydraulic systems Ultra deepwater applications Long tieback distances Electro-hydraulic components failures Environmental Issues 10 - TEPUK Subsea Europe 30/10/08 Enhanced Functionality Response times Condition monitoring Performance trending
The challenge of HP/HT subsea developments Kessog field 15 000 psi 185 deg.c 73 tons 11 - TEPUK Subsea Europe 30/10/08
Significance for the North Sea Subsea developments allow 1) To develop small or marginal reservoirs with tie-back to existing infrastructure 2) Extend production plateau of our mature fields 3) To develop deepwater discoveries 1983 : First Gas of North East Frigg Subsea Template, Field control from articulated column 2002 : Otter First Oil, 3 production wells equipped with ESPs for artificial lift FRIGG FIELD ELECTRICAL CABLE MeOH LINE TEMPLATE 16 SEA LINE FIELD CONTROL STATION UMBILICALS INSTRUMENT CABLES 12 - TEPUK Subsea Europe 30/10/08
North Sea - Subsea to extend production plateau The Alwyn Area Story Initial Production in 1987 for 12 years 21 st anniversary celebrated last june and another 20 years still to go Alwyn North Fields Dunbar Platform & Rig 13 - TEPUK Subsea Europe 30/10/08
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The Alwyn Area example First Gas in 1987 1st subsea well PN1 1988 Production forecast 140 15 - TEPUK Subsea Europe 30/10/08
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The Alwyn Area example Ellon & Grant 1994-98 17 - TEPUK Subsea Europe 30/10/08
The Alwyn Area example Tie back of Nuggets 2001 68 Kms tie-back -10 Subsea control from Dunbar Trunkline always operates in hydrates region Horizontal trees 18 - TEPUK Subsea Europe 30/10/08
19 - TEPUK Subsea Europe 30/10/08 Forvie 2005 1 subsea well 1 subsea manifold for future tie-backs
The Alwyn Area example JURA 2008. ISLAY 2010. Islay Historical fields have their life extended 140 20 - TEPUK Subsea Europe 30/10/08
Jura Project - UK Fast Track Project : First Gas May 08, only 17 month after discovery One of the largest discovery for TEPUK. Increase Alwyn Area remaining reserves by 50% (170 Mboe) Capacity 8Mscmd (50,000 boepd) The field is located in 113 m water depth, 32km from Alwyn and 20km from Dunbar 2 well subsea tieback to existing Forvie Subsea Manifold 3km bundle integrating all process functions HP/HT development (600b / 120 C) 21 - TEPUK Subsea Europe 30/10/08 Innovation IL3 Subsea HIPPS Communication through Optic Fiber Largest Bundle towhead ever installed Chemical Injection Metering Valve
Deep water challenge West of Shetland -Laggan & Tormore A New Subsea Challenge Laggan field discovered in 1986 (Block 206/1a) Tormore field discovered in 2007 (Block 205/5a) Production Capacity 500 MMscfd 125km north west of the Shetland Island 600 m water depth 2 six slot template manifolds Provision for subsea compression in the late field life 22 - TEPUK Subsea Europe 30/10/08
Going to the West of Shetlands Harshest environment in UK Extreme waves : 100yr Hs-18m; Hmax 33m Persistent weather little / no calm High winds, low water temperatures,strong currents 600m Laggan Site - Wave Height (1 Year Return Period) 30 Weather Window 25 20 = 11.6m Metres 15 Hs Hmax 10 _ TEPUK Subsea Europe 30/10/08 5 0 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Source : Metocean Criteria for the Laggan Field (UK Block 206/1). PhysE 28th October 2005
Laggan /Tormore Long tie back Alternative Sullom Voe Subsea Production System (600m water depth) Laggan & Tormore (5 + 3 wells) 140km Multiphase Pipelines (500 MMscfd) 2 x 18 gas lines rock dump material Tormore St Fergus New 500 MMscfd Gas Processing Plant at Sullom Voe 374km 24 Gas Export Pipeline SVT to St Fergus 500 MMscfd Laggan-Tormore chemical injection line control umbilical 24 - TEPUK Subsea Europe 30/10/08
Total E&P UK Operated Production Operated Production in kboe/d 400 350 300 250 200 150 100 50 0 2001 2003 2005 2007 2009 2011 2013 2015 2017 2019 60% 50% 40% 30% 20% 10% 0% Operared Platform Production Operated Subsea Production Percentage of Subsea Production In 2007, 20% of TepUK production was Subsea From 2013 onwards, it will be 50% 25 - TEPUK Subsea Europe 30/10/08
Subsea Developments - Key to Success- Lessons learnt Dedicated project team For engineering phase, tenders, project phase Comprehensive Testing programme treated as key commissioning activities Qualification testing for all new components System testing ( FAT for each item + integration ) External Interface Testing Operational Testing Dedicated team of inspectors provided by the operator Early Involvement of end users 26 - TEPUK Subsea Europe 30/10/08
Subsea Systems The Downside Systems Obsolescence Parts no longer available Often for relatively new systems Vendors Focus on big new projects Lack of interest in older systems Lack of personnel to support the systems Solution to obsolescence is to sell a new system whilst withdrawing support to the older systems New Systems Quality control reduced. Systems appear to be in place, but are the people there? Corporate Knowledge (Vendor and Operator) are we repeating past mistakes? Leaks due to materials Correct ones specified Wrong ones installed Global efficiency of subsea production below platform production Problems often appear very early after installation and require long recovery procedures. 27 - TEPUK Subsea Europe 30/10/08
Subsea Systems The Downside Support DSVs / ROVSVs Shortage unable to readily obtain vessels for rapid intervention New vessels coming onto the market Where are the experienced crews / engineers / divers to man them? Cost Competence Lack of training Vendor personnel Operator personnel Two contradictory assumptions prevalent: Instrument subsea is the same as an instrument topsides. It s a black box, we need the vendor. 28 - TEPUK Subsea Europe 30/10/08
Subsea production Potential improvements Tie-back to a platform Primary importance to get first oil in time followed by a sustainable production Reliability of systems to be improved Quality control Requirements for Routine maintenance to be minimized : difficult and expensive Unplanned incidents cost huge loss of production Long term operability of subsea systems must become a major trend for improvement, Operability of long subsea tie-backs is field proven but not yet a routine operation, Impact of subsea developments on topsides often under estimated, Standardization : Typical project approach going systematically for tenders is not compatible with standardization of subsea equipment, what can we do? General lack of competency, lack of inspection resources, are we doing enough? 29 - TEPUK Subsea Europe 30/10/08
Conclusion Subsea, significance to the UK UKCS is a mature production area (38 Billion barrels already produced) 10 to 15 remain to be produced, 5 to 10 yet to be discovered 90 % of new developments mobilize less than 50 MBoe, most below 20. Existing Infrastructure + Existing Subsea technology available in the UK are well adapted to this problematic. However success will be very dependant of the price of oil and capacity of the industry to keep costs at an acceptable level. Today, and specially today, such costs are not at a reasonable level in the UK. 30 - TEPUK Subsea Europe 30/10/08
31 - TEPUK Subsea Europe 30/10/08 Thank you for your attention