Classification: Statoil internal Status: Draft. Key Technology Challenges. Flow Assurance and Subsea processing

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1 Classification: Statoil internal Status: Draft Key Technology Challenges Flow Assurance and Subsea processing Presented by Pål P l Hedne

2 Technology Development in Statoil A 20-year History of Successful Technology Implementation 2 New technology Subsea & floating Åsgard Glitne Subsea to land Snøhvit Platform based Statfjord satellites Troll Norne Sleipner 1997 Statpipe Gullfaks Significant step changes Time

3 [km] Development of Statoil s s subsea systems rd generation 4 th generation Kristin Snøhvit st generation Gullfaks, Tommeliten 2 nd generation Sleipner sat, Statfjord sat, Heidrun water inj. Yme, Norne, Lufeng, Åsgard, Gullfaks sat / Accumulated length of Statoil operated multiphase pipelines 0 Time

4 4 A global subsea position Subsea wells by major operator (Oct. 2005) Statoil developments (Nov. 2005) 541 Petrobras Statoil Shell ExxonMobil BP Norsk Hydro Chevron Kerr-McGee 81 Total 80 Talisman Source: Infield System Ltd

5 Operations in 30 countries 5 Mexico USA Venezuela Ireland Belgium Norway Denmark UK France Algeria Nigeria Sweden Libya Estonia Latvia Russia Lithuania Poland Kazakhstan Germany Azerbaijan Turkey Iran Saudi Arabia Qatar United Arab Emirates China Singapore Angola Brazil

6 6 Sub-ice operation Deep water Harsh environment Environmental sensitive Long to ultra long distances Ultra deep water Long tie-backs Benign to moderate metocean Technology stretch Areas Time & complexity Technology stretch to Innovation

7 Subsea Production Systems R&D Main Objectives 7 Increased and accelerated recovery Enabling long range well stream transfer Deep water production

8 Increased and Accelerated Recovery Priority Areas and Technology Elements 8 Increase fluid handling capacity Subsea separation and sand handling management Subsea water (re-)injection Power supply and distribution Reduced well head pressure Subsea pumping Wet gas compression Flow improvers Artificial lift Integrated operations Fibre optic sensor and data transfer Data integration Update of models for real time decision making Work processes for multi disciplinary operations

9 9 Deep Water Production Challenges Deepwater fields in harsh environments ( m wd) Ultra deepwater fields in GoM, Brazil and West Africa ( m wd) Deepwater fields in arctic environments ( m wd) Value creation Increase oil recovery Accelerate production Reduce # of drainage points Reduce cost Enable development options

10 Arctic Production Large Potential 10 Global undiscovered oil and gas resources Total: 1,634 bn boe Svalbard Rest of the world Shtokman Arctic Southern Barents Sea Pechora Sea Varandie North Africa, Middle East and the Caspian Snøhvit Melkøya Murmansk Source: USGS, World Petroleum Assessment.

11 11 Long Range Well Stream Transfer Produce anywhere in the Arctic by 2030 ÅSGARD KIRKENES MURMANSK MELKØYA NORDKINN SPITSBERGEN SHTOKMAN PECHORA SEA NOVAYA ZEMLYA VARANDEY KARA SEA YAMAL SNØHVIT

12 Arctic Field Development Ice Handling 12 Shallow water: Manage the ice Deeper water: Avoid the ice

13 The Flow Assurance Challenge 13 Flow Assurance Thermal issues Multiphase flow Hydrate Corrosion Wax Erosion Scale Sand production Asphaltene The ability to produce multiphase fluids from reservoirs to processing plants in an economically and technically feasible way

14 Multiphase Gas-Condensate Systems Liquid load Flow Challenges Boosting 14 pipeline liquid content (m³) Equilibrium situation for steady state production Inlet pressure (bara) Total liquid content (m³) MEG/water content (m³) Inlet pressure (bara) Flowrate (MSm³/sd) 70

15 Multiphase Gas-Condensate Systems Fluid Challenges 15 Hydrates Low water production Fully inhibited system Depressurisation Corrosion Chemical inhibition ph stabilized MEG Concept: Bare carbon steel pipe lines Fluid temperature at ambient sea temperature Inspection pigging, only Broad operational experience Scale Chemical inhibition

16 Multiphase Gas-Condensate Systems Well Stream Transfer Length Boosting 16 Transfer length [km] Shtokman Snøhvit Year Issues Gas compression Power supply Hydrate remediation Remote control Can in principle be stretched very long

17 17 Long distance multiphase transfer 250 Planned In operation red = Statoil operated Tyrihans Condensate-gas ratio (CGR) (bbls/mmscf) Erskine Malampaya Popeye East Spar Mikkel Goldeneye Midgard Gorgon South Pars Snøhvit Mexilhao Ormen Lange Huldra Troll Scarrab-Saffran TOGI Canyon- Mensa Kvitebjørn Express Corrib Current operational experience Transfer distance (km) Nam Con Son (2-P) (399)

18 Multiphase Oil Systems Flow Challenges 18 Boosting Dynamic Behaviour Pressure [bar] Temperature Time [h]

19 Multiphase Oil Systems Fluid challenges 19 Hydrates Corrosion Scale Wax Temperature! Emulsion Asphaltenes

20 Multiphase Oil Systems Traditional Pipeline Transportation Mode 20 Concept include: Fluid temperature above hydrate appearance temperature Isolation/heating necessary Injection of hydrate inhibitor during shut-down Wax control by regular loop pigging Current design < 50 km Future applications: Future applications: Possible extension to km Direct electrical heating (DEH) Subsea separation and boosting

21 Multiphase Oil Systems Cold Flow Pipeline Transportation Mode 21 Concept: Fluid temperature at ambient sea temperature Extended water removal and traditional hydrate inhibition or Dry hydrate particle generation Bare carbon steel pipe lines Wax control Subsea pig launching No operational experience Future applications: Future applications: Can in principle be stretched very long Includes comprehensive subsea processing

22 Multiphase Oil Systems Well Stream Transfer Length 22 Transfer length [km] DC power or Local power generation Tyrihans Year Issues Fluid conditioning Pumping Power supply Remote control Existing technology can be stretched to ~ 200 km Comprehensive step out to extend >> 200 km

23 23 Long distance multiphase transfer 1000 Planned In operation red = Statoil operated 900 Oil-gas ratio (CGR) (bbls/mmscfd) Extended insulation/- heating solutions Cold flow Current operational limit Transfer distance (km)

24 Enabling Long Range Well Stream Transfer Sub-sea power transfer and local power distribution Sub-sea field centre -separation -pressure support: gas lift and water injection -compression and boosting Long distance pipeline transport technology -multiphase fluid -oil dominated fluid The Arctic Challenge Sub-sea Gas field development current status/ambitions: Sub-sea Oil field development current status/ambitions: Ambitionby 2030, nolimit Ambitionby 2030, nolimit Ambition by 2010, 500km Ambition by 2010, 200km Currentlimit 140 km Currentlimit 50 km Ship transport technology in ice -off loading -terminals and harbours 1. No ice coverage 2. Ice covered part of the year 3. Permanent ice covered 4. Partly/permanent ice covered and water depth < 50m Environmentally responsible operations

25 Subsea Processing Field Development of the Future 25 Remote control Power distribution Re-injection of produced water Separation, pumping, and compression Inspection and maintenance Wax and hydrate conditioning Subsea hub with spare processing capacity for future tie-ins of satellites

26 Statoil's first subsea processing application Lufeng 26 Lufeng 22-1 on-stream Dec horizontal production wells 5 subsea booster pumps 7 years of operational experience. A small field development with cost effective development solution Key data: Multipurpose shuttle tanker 333 m water depth 9000 bbl per day 75% Statoil / 25% NOOC

27 Tordis Subsea Separation, Boosting, and Injection 27 Worlds 1st commercial subsea processing plant to be started up in 2007 Existing Tordis subsea PLIM Features: Bulk water separation Multiphase boosting Water and sand injection Animation SSBI station WI Well

28 Tordis System Configuration 28 Design basis: Oil flow rate: Sm³/d Water flow rate: Sm³/d Gas flow rate: 1.0 MSm³/d Sand rate: kg/day Op. pressure: 25 bar Op. temp.: 75 C

29 TYRIHANS 29

30 30

31 31 Future subsea challenges and opportunities Arctic production: Stepwise Development 2020? Subsea compression plant Large step-out, large duty Snøhvit/Troll: ? Subsea compression plant. Large step-out Åsgard: Subsea wet gas compressor 2 x 6 MW Tyrihans: 2009 Tordis: 2007 Subsea sep km step out Subsea raw seawater injection 9 Sand handling 2 x 3 MW 35 km step out 2 x 2,5 MW, 12 km 9Sanctioned

32 Future step changes Subsea System Development HV Power Local Power Generation DC 32 Sub-ice AC mod. AC 300 km 600 km 200 km Time

33 Subsea Processing Status World Wide I 33 Boosting and injection ~15 pumps worldwide MW (SPP and MPP) 2.5 MW at Tordis 2007 and Tyrihans 2009 MPP ΔP=30-40 bar, Q ~ 1500 m3/h Compression Åsgard 2011, 6-8 MW Ormen Lange , 12.5 MW Separation Water/oil, Troll Pilot 2001 Water/oil/sand, Tordis 2007 No compact equipment qualified subsea

34 Subsea Processing Status World Wide II 34 High power distribution ~10 km today Tordis 12 km 2x2.5 MW 2007 Tyrihans 45 km 2x2.5 MW 2009 Åsgard compression 47 km 1x6-8 MW 2011 Direct electrical heating Direct electrical heating ~10 km today Tyrihans 45 km 2009

35 The Way Forward is 35 Subsea Processing and Long Range Wellstream Transfer Fluid Conditioning Pressure Boosting Power Supply Prediction Tools Remediation Tools Production distance Gas dominated Oil dominated Comprehensive technology development needed next 10 years to extend technology to meet our business challenges

36 36 Welcome to Subseaville and thank you for the attention!