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Presentation of Statoil ASA

Presentation of Statoil ASA. UK Norway Share fair 2006 Aberdeen, Scotland, 20th April 2006. Statoil in brief. Statoil is an integrated oil and gas company with activities in 33 countries (exploration and production in 15 of these)

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Presentation of Statoil ASA

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  1. Presentation of Statoil ASA UK Norway Share fair 2006 Aberdeen, Scotland, 20th April 2006

  2. Statoil in brief • Statoil is an integrated oil and gas company with activities in 33 countries (exploration and production in 15 of these) • At 31 December 2005 Statoil had 25,644 employees, and 49 percent work outside Norway • Statoil operates 24 oil and gas fields on the Norwegian continental shelf and accounts for 60 percent of all Norwegian petroleum production. As operator for 23 seabed facilities, Statoil is a leader in sub sea production • International production is growing strongly • We are one of the world’s largest sellers of crude oil and a substantial supplier of natural gas to the European market

  3. Statoil – highlights in 2005 • Statoil’s total revenues came to NOK 393 billion • Net income was 30,7 billion – the best ever in Statoil’s history • Extensive acquisitions of fields and exploration licences in the Gulf of Mexico, with first field development initiated • New vigour on the Norwegian continental shelf • Technical innovation • 12 new developments • 9 discoveries • 16 new licences awarded • Record-high reserve replacement ratio

  4. Corporate executive committee Helge LundPresident and CEO Terje OvervikExploration & Production Norway Peter Mellbye International Exploration & Production Rune BjørnsonNatural Gas Jon Arnt JacobsenManufacturing & Marketing Margareth ØvrumTechnology & Projects Eldar SætreChief financial officer Nina Udnes TronstadHealth, safety and the environment Jens R JenssenHuman resources Reidar GjærumCorporate communication

  5. Core areas on the NCS Harstad Halten/NordlandGrowth area TampenMatured area Stjørdal Bergen Core areas Stavanger Troll/SleipnerGas machine Offices Fields operated by Statoil

  6. Core area:Troll/Sleipner • “Main engines” in the Norwegian gas machine • Provide 63 per cent ofStatoil’s gas production • Contain 52 per cent of Statoil’s gas reserves The Sleipner A integrated production, drilling and quarters platform is linked by a bridge to the Sleipner T gas treatment installation

  7. Core areas:Tampen – Statfjord, Gullfaks, Snorre, Visund, Kvitebjørn Challenges: • Improve oil recovery • Extend producing life • Coordinate and enhance efficiency Embraces the oldest and largest fields A new shift arrives on the Statfjord A platform while another goes home.

  8. Core areas:Halten/Nordland –Heidrun, Åsgard, Norne, Kristin New solutions: • Production ships • Floating platforms • Extensive use of subsea installations • New developments in deep water • A new gas province Åsgard A is one of the world’s largest production ships. Its capacity is enough to meet all Norway’s oil needs.

  9. Snøhvit • Statoil will become a player in the market for liquefied natural gas (LNG) • An environmental project without harmful discharges • No surface installations on the field • Carbon dioxide storage beneath the seabed The LNG plant on Melkøya, a few kilometres from Hammerfest.

  10. Gas transport and terminals Snøhvit Melkøya • Export pipelines to Germany, Belgium, France and the UK • High regularity and great flexibility • Statoil is technical operator for 6,000kmof pipeline Norne Heidrun Åsgard Kristin ÅTS Haltenpipe Ormen Lange Statfjord Nyhamna Troll Frigg Kollsnes Vesterled Kårstø Sleipner St Fergus Europipe II Ekofisk Europipe I Langeled Norpipe Teesside Zeepipe I Franpipe Emden Easington Zeebrugge Dunkerque

  11. Corporate executive committee Helge LundPresident and CEO Terje OvervikExploration & Production Norway Peter Mellbye International Exploration & Production Rune BjørnsonNatural Gas Jon Arnt JacobsenManufacturing & Marketing Margareth ØvrumTechnology & Projects Eldar SætreChief financial officer Nina Udnes TronstadHealth, safety and the environment Jens R JenssenHuman resources Reidar GjærumCorporate communication

  12. Procurement & supplier relations

  13. Procurement in Statoil – We strive to • secure best value for money through optimal utilization of in-house and supplier resources to provide products and services with the right quality delivered on-time • meet HSE standards and objectives in work performed by our suppliers • engage suppliers who share our values and apply guidelines ensuring a reputation of high ethical standard, integrity and social responsibility

  14. Procurement in Statoil – How we work (1) • Strategic sourcing • Develop, integrate and implement sourcing strategies, with “One Statoil” in mind, through a category approach to goods and services based on aggregated demand management, the global market situation and robust analysis to minimize execution risk • Base procurement on competitive bidding, taking into account the principles of transparency, non-discrimination and equal treatment of bidders • Address country specific requirements affecting procurement together with cultural and ethical issues

  15. Procurement in Statoil – How we work (2) • Segregation of duties, Compliance and Control • Line management is responsible for demand planning, allocation of technical and operational competence, for budgets and approval of recommended suppliers • Procurement entities are responsible for pro-active demand coordination, planning and execution of procurement on behalf of line management to commit Statoil towards the supplier in accordance with delegation from the CPO • Support cost effective procurement through simple and standardized tools, systems and work processes securing quality, efficiency, spend transparency and appropriate automation

  16. Statoil Group Procurement 1996-2005 Yearly spend (NOK Bn) Committed Value Invoiced Value * Invoiced Value 2003 does not include commitments without Purchase Orders

  17. Statoil Group Procurement 2005Spend per Product/Service Area Total Procurement: 62,8 NOK Bn

  18. Norway: • Shift in portfolio to increased focus on Modification/tie-in and revamp • Still large Projects in the funnel Graf

  19. Concept Engineering (DG2)

  20. Gjøa Field Development ÅTS Langeled Camilla&Belinda Camilla&Belinda Gjøa Gjøa Tampen Tampen Kvitebjørn Kvitebjørn Valemon Valemon Huldra Huldra Troll Troll Hild Hild Oseberg Oseberg Gjøa recoverable reserves: • Gas 39 GSm3 • Oil/condensate 10 MSm3 Gjøa licence partners: • Statoil (Development operator): 20 % • Gaz de France Norway (Operations operator): 30 % • Petoro: 30 % • Shell: 12 % • RWE Dea: 8 %

  21. Gas Oil Gjøa and CBB Field Development Concept GJØA SEMI WELLS RICH GAS/STAB. OIL EXPORT Umbilical Gas 10” GJØA NORTH Oil 10” Lift gas 6” 22 – 28”” 130 km PIPELINE 7 km Umbilical Gas 12” GJØA SOUTH Oil 12” Lift gas 6” 4 km 16” OD, 60 km PIPELINE Umbilical CAMILLA Gas 14” BELINDA 50 km FRAM B EL. POWER FROM MONGSTAD, 100 km GAS OIL

  22. Gjøa subsea layout D Gas 10” ID for E and D 12” ID for B CRA steel 3.4 km Oil 10” ID for E 12” ID for B CRA steel SEMI C&B A E 7.2 km Gas Lift 6” carbon steel Umbilical 4.4 km Gas export B C UTM coordinates: SEMI 6804200/548000Template B & C 6801300/551300Sat D 1 slot 6806200/552700Template E 6803900/555200 Oil export Power cable

  23. Infrastructures in the Troll area

  24. Heimdal Troll B FUKA Vesterled St.Fergus Miller Zeepipe 2A CATS Sleipner Teesside West 25 Concepts • Troll B to Vesterled sub-sea • Gassled Area D reinforcement by ZP IIA – Miller • Troll B to HRP and split between FUKA and Vesterled • Gassled Area D reinforcement by ZP IIA – CATS • Troll B direct to Miller • Troll B direct to St Fergus

  25. East 30 & 40 Concepts St.Fergus Kollsnes Miller • Kollsnes direct to Miller • Kollsnes direct to St Fergus • Kollsnes direct to Zeebrugge • Kollsnes direct to Den Helder Zeebrugge Den Helder

  26. Troll Future DevelopmentPipeline alternatives from Kollsnes • Direct to Zeebrugge (1050 km) • 42” pipeline with a capacity of 57 MSm³/d • Direct to Den Helder (870 km) • 42” pipeline with a capacity of 60 MSm³/d • Direct to St.Fergus (500 km) • 40 MSm³/d (32”) • 65 MSm³/d (38”) • Via Miller to St.Fergus (285 km) • Depending available spare capacity • 28” – 34” • Third line Troll A to Kollsnes (65 km) • 36” (landfall section pre-installed)

  27. Kårstø Developments 2006-2015

  28. Kårstø, key processing unit oil and gas production from Norwegian Continental Shelf Draugen Heidrun Mikkel Norne Åsgard Kristin Skarv 2010 Åsgard rich gas Statpipe Sales gas Draupner Brage, Gullfaks, Jotun, Balder, Snorre, Statfjord Sygna, Tordis, Veslefrikk, Vigdis, Visund New Tampen vol? Statpipe Rich gas Dornum Europipe II Sales gas Sleipner Vest Sleipner Øst Gungne Sigyn Sleipner Condensate

  29. Kårstø Master plan • Modernise the Kårstø plant to: • Improve technical integrity • New business opportunities: • New fields/volumes • Increased capacity utilisation • Previous Kårstø developments • Statpipe 85, Sleipner 93/96, • Åsgard 00, Mikkel 03, KEP 05

  30. Status and Way forward • Kårstø has a significant project portfolio ahead: • High activity within maintenance and modifications • Significant project portfolio • Total investments in the next 10 years may be 9 – 10 GNOK • Maintenance and modification portfolio to be executed within Operation • Project portfolio to be executed in two phases • Phase 1, Completion by 2010/2011 (5 GNOK) • Phase 2, Completion by 2013-2015

  31. New solutions - new watersNew technology has opened for northern activity History Future Arctic E&P Ultra Deepwater Environmental technology Snøhvit LNG Troll 1995Åsgard 1999 Statpipe 1985 Statfjord 1979 18

  32. Uranus Obelix Guovca Goliath 4,2 Gas 4,0 Oil 16,8 Edvarda 9,8 Midnattsol Tulipan 4,9 11,5 2,8 2,6 Kogge * Undiscovered resources (Bn bbl. o.e.) Source: Statoil Significant opportunities in frontier areas • Barents Sea • Four wells, where two are Statoil-operated: Uranus and Guovca • No commercial discoveries in Obelix and Guovca • Norwegian Sea; deep water • Three Statoil-operated wells • Small gas discovery in Tulipan wildcat • North Sea • Kogge wildcat in southern North Sea • Significant yet-to-find potential • 28 Gboe undiscovered on the NCS Total*

  33. Snøhvit I&II Area G Area F Shtokman Long term visions for the Barents SeaIndustrial options we are working towards Zeebrugge Emden • Short term (2012) • Snøhvit I & II • Pechora olje • NEGP • Shtokman I • Area F & G • Medium term (2020) • Barents West piped gas • Shtokman II • Long term (2020+) • Shtokman III • Pipeline gas to Europe Kårstø Kollsnes Nyhamna Åsgard Tromsø Murmansk Kirkenes Melkøya Barents West

  34. Summary • Still a significant number of possible new projects, but • cost level is increasing significantly (CAPEX/bbl) • lack of capacity • High focus on continued development of the Norwegian shelf • Increased oil and gas recovery • Smaller field development and satellites • More complicated/challenging reservoirs • A number of projects require modification on existing infrastructure

  35. Thank you!pjt@statoil.com

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