eksperter i team – gullfakslandsbyen 2009
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Eksperter i Team – Gullfakslandsbyen 2009. Reservoar og IOR – oppgave 2, 3 & 5 Petter Eltvik, StatoilHydro UPN, Ledende reservoaringeniør Gullfaks området. Gullfaks Landsbyen 2009……. Fortsatt mye ugjort på Gullfaks……… IOR-potensialet tilsvarer et nytt stort satelittfelt - PowerPoint PPT PresentationTRANSCRIPT
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Classification: Internal Status: Draft
Eksperter i Team – Gullfakslandsbyen 2009
Reservoar og IOR – oppgave 2, 3 & 5Petter Eltvik, StatoilHydro UPN, Ledende reservoaringeniør Gullfaks området
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Gullfaks Landsbyen 2009…….
• Fortsatt mye ugjort på Gullfaks………
• IOR-potensialet tilsvarer et nytt stort satelittfelt
• Vurderer IOR prosjekter som kan bidra til fortsatt verdiskaping i denne rike provinsen
• Krevende og utfordrende IOR-arbeid for å nå høye ambisjoner
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Structural Depthmap – Base Structural Depthmap – Base CretaceousCretaceous
Area : 50 km2
Top Structure : 1700 m TVD
Dipping : 0-20 West
Oil-water contact : 1947 m TVD
Initial pressue : 310 bar
Bubblepoint pressure : 220 bar
Initial temprature : 72 deg C
Formation volume factor : 1,2
Oil viscosity : 1.2 cp
Oil gravity : 36.9 API
Gullfaks reservoir data
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“Til siste dråpe”Hvilke virkemidler har gitt oss denne utviklingen?
Reservoarkunnskap og -styringReservoarkunnskap og -styring
4D seismikk / monitorering4D seismikk / monitorering
Omfattende innfyllende Omfattende innfyllende
boring og brønningrepboring og brønningrepVann og gassinjeksjonVann og gassinjeksjon
Development of expected recovery 1986 1996 2000 2007
Statfjord 49,4 % 61,4 % 65,6 % 70 %Gullfaks 46,5 % 49,4 % 54,5 % 70 %
Utblokking avUtblokking avprosessanleggprosessanlegg
Smarte brønner Smarte brønner
AMEOR og EORAMEOR og EOR
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ProduksjonsprofilerTilleggsreserver ved senfaseutvikling 2006 – 2020+?
Profil 1999 - IOR: +190 mill. Sm3
Basis profil 1982
Profil 1988 - Aksellerasjon
Tillegg v.h.a.IOR?70% ?
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Implemented Oil Recovery Measures at Gullfaks
• Water injection from start
• Upgrading of water injection capacities
• 4D seismic and inversion
• Tracers
• Hydraulic fracturing in low perm reservoirs
• WAG (Water alternating gas) injection
• ”Huff and puff” gas injection
• Extensive exploration activity within drilling reach from platforms => new volumes
• Sand control in most wells
• ”Designer wells” (horizontal, 3D)
• Extended reach drilling (10 km)
• Monobore completions
• DIACS -”Smart wells”
• Multilateral wells (ML)
• Coiled Tubing drilling (CT)
• Through tubing drilling (TTRD)
• Rig assisted snubbing (RAS)
• Underbalanced drilling (UBD)
• Expandable liners
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Oil Recovery Measures studied
Studied, but discarded:
• Surfactant injection (1992 pilot)
• Gel blocking (1992 pilot)
• CO2 miscible injection (2000)
• Aerobic Microbiological EOR
(2006)
Currently being studied:
• Reservoir characterisation, remaining saturation and relative permeability
• Temprature effects
• Building new reservoir simulation models
• WAG evaluations
• EOR with water based methods
• CO2 studies
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Well targets
Gullfaks in the past and present;
Steak vs. ragu
Gullfaks
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IOR potensialer i plattformfelt fordelt på tiltakstype(mill Sm3 olje)
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Tiltakstype
Økte kapasiteter
Blandbar injeksjon
Økt vannsirkulering
Utfyllende boring
Uøkonomisk hale
senfasetrykkavlastningMulig ny teknologi(ambisjon)
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Nåværende drenering Oljehale Endret drenering
IOR – et deltaprosjekt Planlegger i forhold til en usikker basislinje
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Classification: Internal Status: Draft
Oppgave 2 IOR i Cook fm i segment I1
Hvordan oppnå maksimal utvinning av olje i et segment som i dag har en utvinningsgrad på 12 %.
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Classification: Internal Status: Draft
Oppgave 3 Temperatureffekter pga vanninjeksjon
Vanninjeksjon har ført til redusert temperatur i reservoaret noe som bl. a. påvirker formasjonsstyrke og elastiske egenskaper.
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13Reservoir Quality
• Reservoirs: Brent, Cook, Statfjord & Lunde
• Very faulted and eroded, with contrasting layers and weak formations
• Dip up to 12 o in the western part.
• Porosity (Brent): 30-35 %
• Permeability (Brent): 10 D – 10 mD
West East
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”Map” of Gullfaks Main Field
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15Top DrakeTop NERTop Ness
Top Tarbert
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Visualization of temperature distribution in segment H1 after 20 years of seawater injection.
Top left: south – north cross-section through A-35 (well to the left).
Bottom left: Layer 48, i.e. R-1. Well A-35 is seen in the bottom
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Comparison of measured and simulated bottom hole temperaturein two producers in segment H1
55.0
57.0
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61.0
63.0
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73.0
75.0
28.10.95 11.3.97 24.7.98 6.12.99 19.4.01 1.9.02 14.1.04 28.5.05 10.10.06 22.2.08 6.7.09
oC
A-39A_Mea B-37_Mea B-37 A-39A
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Production in H1 - lower Brent
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okt.86 jul.89 apr.92 jan.95 sep.97 jun.00 mar.03 des.05
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mnd
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GOR
Oil rate WCUT GOR
Waterinjection and productionH1 - lower Brent
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jul. 86 apr. 89 des. 91 sep. 94 jun. 97 mar. 00 des. 02 sep. 05
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Water production Water injection
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Oil and water properties