Presentation of Statoil ASA
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Transcript of Presentation of Statoil ASA
Presentation of Statoil ASA
UK Norway Share fair 2006
Aberdeen, Scotland, 20th April 2006
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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
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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
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Corporate executive committee
Nina Udnes Tronstad
Health, safety and the environment
Helge LundPresident and CEO
Margareth ØvrumTechnology &
Projects
Terje OvervikExploration & Production
Norway
Peter Mellbye International Exploration
& Production
Rune BjørnsonNatural Gas
Jon Arnt JacobsenManufacturing &
Marketing
Eldar SætreChief financial officer
Jens R JenssenHuman resources
Reidar GjærumCorporate
communication
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Harstad
Stjørdal
Bergen
StavangerCore areas
OfficesFields operated by Statoil
Core areas on the NCS
Halten/NordlandGrowth area
TampenMatured area
Troll/SleipnerGas machine
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Core area: Troll/Sleipner•“Main engines” in the
Norwegian gas machine
•Provide 63 per cent of
Statoil’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
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Core areas:
Tampen – Statfjord, Gullfaks, Snorre, Visund, Kvitebjørn
Challenges:
• Improve oil recovery
•Extend producing life
•Coordinate and enhance
efficiency
A new shift arrives on the Statfjord A platform while another goes home.
Embraces the oldest and largest fields
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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.
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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 seabedThe LNG plant on Melkøya, a few kilometres from Hammerfest.
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Gas transport and terminals
•Export pipelines to Germany,
Belgium, France and the UK
•High regularity and
great flexibility
•Statoil is technical
operator for 6,000km
of pipeline
Nyhamna
Europipe II
Europipe I
Norpipe
Emden
Teesside
ÅTS
Norne
Åsgard
Haltenpipe
Heidrun
Franpipe
Zeebrugge
Zeepipe I
St Fergus
Vesterled
Frigg
Statfjord
Kårstø
Kollsnes
Melkøya
Snøhvit
Ormen Lange
Easington
Langeled
Ekofisk
Sleipner
Troll
Dunkerque
Kristin
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Corporate executive committee
Nina Udnes Tronstad
Health, safety and the environment
Helge LundPresident and CEO
Margareth ØvrumTechnology &
Projects
Terje OvervikExploration & Production
Norway
Peter Mellbye International Exploration
& Production
Rune BjørnsonNatural Gas
Jon Arnt JacobsenManufacturing &
Marketing
Eldar SætreChief financial officer
Jens R JenssenHuman resources
Reidar GjærumCorporate
communication
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Procurement & supplier relations
CPO
Drilling & well
Key supplier
Relations
Market analysis
Corporate
Procurement
support services
•HR
•HSE
•Rig strategy
•BPP initiative
Constructions
and
modifications
Steel
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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
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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
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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
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Statoil Group Procurement 1996-2005 Yearly spend (NOK Bn)
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44,4 41,9
30,726,8
36,9
50,5
62,8 62,8
33,7
1996 1997 1998 1999 2000 2001 2002 2003* 2004 2005Committed Value Invoiced Value
* Invoiced Value 2003 does not include commitments without Purchase Orders
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Statoil Group Procurement 2005
Spend per Product/Service Area
Total Procurement: 62,8 NOK Bn
Unclassified11 %
R&D1 %
Ops., Mod., Maint.12 %
Administrative13 %
Project Development
46 %
Drilling&Well17 %
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-Business idea-Exploration
Project planning Project executionFeasibility Concept Detail engineeringPre-engineering Construction Completion
IPR 1 IPR 2 IPR 3 0PR
DG 0Feasi-bility
AP 1 AP 2
Operation
The project development process
DG 1(BoK)
DG 2(BoV)
DG 3(BoG)
DG 4(BoD)
-Business idea-Exploration
Project planning Project executionFeasibility Concept Detail engineeringPre-engineering Construction Completion
IPR 1 IPR 2 IPR 3 0PR
DG 0Feasi-bility
AP 1 AP 2
Operation
The project development process
DG 1(BoK)
DG 2(BoV)
DG 3(BoG)
DG 4(BoD)
Graf
New Major Pipelines10 %
Modifications /Tie-ins42%
Stand Alone35 %
Onshore New Build
7%
Onshore Modification
10 %
Norway:
•Shift in portfolio to increased focus on Modification/tie-in and revamp
•Still large Projects in the funnel
19Concept Engineering (DG2)SOL Projects Sanction Field Location Project Type
Mongstad PQP Fase 2 Dec 2006 Mongstad Mod.
SFC WI to Vigdis / Snorre Jun 2006 Statfjord, Vigdis Mod., Pipeline
Alve Oct 2006 Alve, Norne Mod., Subsea
GJØA w/ Camilla Belinda Nov 2006 Gjøa, Gullfaks Semi, Subsea, Well
Snorre / Vigdis IOR Dec 2006 Vigdis Mod., Module
Dagny Dec 2006 Troll, Sleipner Mod., Subsea, Well
Alpha Sør Dec 2006 Troll, Sleipner Subsea, Tie-in, Well
Snorre B IOR Topside Dec 2006 Vigdis Mod. , Module
Kårstø Modifications Apr 2007 Kårstø Refinery Mod.
Etan Dornum Aug 2007 Dornum Etan/CO2 Plant
Gudrun Jan 2008 Gudrun, Sigrun, Sleipner Stand Alone
Troll Future Development May 2008 Troll, SleipnerMod. Troll A, Kolsnes
Extension, New Pipeline
Heidrun Gas Injection Jul 2008 Heidrun Mod. , Module
Valemon Oct 2008 Valemon, Kvitebjørn Mod., Subsea, Well
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Gjøa Field Development
Gjøa licence partners:
• Statoil
(Development operator): 20 %
• Gaz de France Norway
(Operations operator): 30 %
• Petoro: 30 %
• Shell: 12 %
• RWE Dea: 8 %
Gjøa
Kvitebjørn
Camilla&Belinda
ValemonHuldra
Hild TrollOseberg
TampenGjøa
Kvitebjørn
Camilla&Belinda
ValemonHuldra
Hild Troll
Langeled
Tampen
Oseberg
ÅTSGjøa recoverable reserves:
• Gas 39 GSm3
• Oil/condensate 10 MSm3
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Gjøa and CBB Field Development Concept
GAS OIL
22 – 28”” 130 km PIPELINE
GJØA SEMI
RICH GAS/STAB. OIL EXPORT
Oil16” OD, 60 km PIPELINE
Gas
GJØA
NORTH
GJØA
SOUTH
Gas 10”
WELLS
Oil 10”Lift gas 6”
Umbilical
Gas 12”Oil 12”Lift gas 6”
Umbilical
UmbilicalGas 14”
CAMILLA
BELINDA
FRAM B
EL. POWER FROM MONGSTAD, 100 km
50 km
7 km
4 km
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Gjøa subsea layout Gas 10” ID for E and D
12” ID for B
CRA steel
Oil 10” ID for E
12” ID for B
CRA steel
Gas Lift 6” carbon steel
Umbilical
Oil export
C
B
E
UTM coordinates:
SEMI 6804200/548000Template B & C 6801300/551300Sat D 1 slot 6806200/552700Template E 6803900/555200
D
SEMI
Gas
expo
rt
C&B
Power cable
A
3.4 km
4.4 km
7.2 km
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Infrastructures in the Troll area
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West 25 Concepts
MillerSt.Fergus
Heimdal
SleipnerCATS
Teesside
FUKA
Vesterled
Troll B
Zeepipe 2A
• 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
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East 30 & 40 Concepts
Kollsnes
Miller
St.Fergus
Zeebrugge Den Helder
9. Kollsnes direct to Miller
10. Kollsnes direct to St Fergus
11. Kollsnes direct to Zeebrugge
12. Kollsnes direct to Den Helder
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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)
Kårstø Developments 2006-2015
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Kårstø, key processing unit oil and gas production from Norwegian Continental Shelf
Brage, Gullfaks, Jotun, Balder,Snorre, Statfjord Sygna, Tordis, Veslefrikk, Vigdis, VisundNew Tampen vol?
Sleipner VestSleipner ØstGungneSigyn
Åsgard rich gas
Sleipner Condensate
Draugen Heidrun Mikkel Norne ÅsgardKristinSkarv 2010
StatpipeRich gas
StatpipeSales gas
Europipe IISales gas
Draupner
Dornum
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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
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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
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History Future
Statpipe 1985
Troll 1995Åsgard 1999
Snøhvit LNG
Statfjord 1979
Environmental
technology
Ultra
Deepwater
Arctic E&P
New solutions - new watersNew technology has opened for northern activity
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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
Kogge
EdvardaMidnattsol
Tulipan
Obelix Uranus
Guovca
Goliath
Oil
Gas
Total*
* Undiscovered resources (Bn bbl. o.e.) Source: Statoil
11,54,9
2,6
4,0
16,8
9,8
2,8
4,2
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Long term visions for the Barents SeaIndustrial options we are working towards
MurmanskMelkøya
Tromsø
Nyhamna
Åsgard
KårstøKollsnes
Emden
Kirkenes
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 EuropeSnøhvit I&II
Shtokman
Barents West
Area G Area F
Zeebrugge
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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
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Thank [email protected]