ekofisk - npd
TRANSCRIPT
Ekofisk The Discovery That Transformed Norway
December 20, 20191
Phillips entering Norway
2
1962Phillips Petroleum in Oslo
1964Legal framework/ borderlines Denmarkand UK
1965FirstLicense round
December 20, 20193
First License Round
• Phillipsgroup (Phillips, Norske Fina, Norsk Agip) awardedthree licenses
• License 016 - Blocks 7/8, 8/1, 16/11 and 17/12• License 017 - Blocks 8/8, 8/10 and 8/11• License 018 - Blocks 1/5, 2/4, 2/7 and 7/11
• License group extended• Phillipsgroup viewed awarded blocks to be too concentrated• Group extended with Petronord group (Elf, Total and Norsk
Hydro)
• Work committment• Seismic acquisition• Drill five 4000m long wells – at least one in each license• By September, 1971
2 3
7 8 9
1
16 17 18
Phillips Group awarded blocks
December 20, 20194
Exploration Drilling – 7/11-1 Cod Field Discovery
1967 1968 1969 1970 1971 1972
• 250 ft of gas and condensate
• Paleocene sand
• Average porosity 20%
• Water saturation 25-35%
• Good flow potential tested throughseveral DST’s
December 20, 20195
Exploration Drilling – Cod Appraisal
1967 1968 1969 1970 1971 1972
• Inplace estimates• 700 BCF and 50 million barrels condensate
• Disappointing results from 7/11-3 and 4
• Too small for sole development
• Uncertain gas market and transport solution
7/11-1 7/11-2 7/11-3 7/11-4
December 20, 20196
Exploration Drilling – 2/4-1
1967 1968 1969 1970 1971 1972
2/4-1
Well kicked at 5450’
Needed to P&A
December 20, 20197
Exploration Drilling – 2/4-2
1967 1968 1969 1970 1971 1972
2/4-1 2/4-2
Aftenposten 28. oktober 1969
Ekofisk Discovery – Entered Reservoir October 25, 1969
December 20, 20199
Ekofisk – Discovery
1967 1968 1969 1970 1971 1972
2/4-1 2/4-2 2/4-3 2/4-5
2/4-4
2/4-1
2/4-2
2/4-4
2/4-3
2/4-5
Ekofisk fm
Tight Zone
Tor fm
• Reservoir Thickness – up to 800ft
• Initial pressure – 7100 psi
• Porosity – 25-45%
• Matrix permeability – up to 2md
• Effective permeability – 10 to 20 times higher
• Initial volume estimates – 4,5 to 6 billion barrels
• Excellent productivity from DST’s
• Recovery factor – 17 to 22%
December 20, 201910
Exploration Drilling – 4Q 1970 – Three Discoveries Made
1967 1968 1969 1970 1971 1972
2/4-6
2/5-1
2/7-1
2/4-7
• 2/7-1 Eldfisk discovery
• 2/4-6 West Ekofisk discovery
• 2/5-1 Amoco Tor discovery
• 2/4-7 Tor appraisal into PL018
• 2/7-4 Edda discovery
• 1/6-1 Albushell discovery2/7-4 1/6-1
December 20, 201911
Greater Ekofisk Area – Discovered Resources ≈14 Billion BOE’s.
1967 1968 1969 1970 1971 1972
West Ekofisk
Tor
Eldfisk
Edda AlbuskjellEkofiskCod
Oil - 10,5 billion barrels
Gas - 3,5 billion barrels oe
December 20, 201912
1971 Early Test Production – 18 Months After Discovery
• From four subsea wells
• Provide reservoir information for field developmentplanning
• Test fractured chalk production behavior
• Provide offshore operational experience
December 20, 201913
Prime minister Bratteli marks first production
December 20, 201914
Greater Ekofisk Area Fields – First Oil 1974
15
2// J 2// M 2// Z 2// L 2// X
2// FTP 2// Q 2// C 2// B H
2// T
2// K 2// B
Ekofisk-funnet Oppstart av produksjonen
Rørledning til Teesside, Storbritannia
Alexander L. Kielland-ulykken
Oppjekking av Ekofisk-senteret
Ekofisk II Vanninnsprøyting på Eldfisk
Oppstart av Ekofisk Sør-prosjektet
Eldfisk II oppstart 50-årsjubileetStart av vann-innsprøyting på Ekofisk
Ekofisktanken ankommer Ekofisk
Ekofisk 2/4 M settes i produksjon
Fjerning av Ekofisk I installasjoner starter
Ekofisk LOFS – 4D seismikk
Rørledning til Emden, Tyskland
1973 The Start of the Concrete Era
December 20, 201916
1975 Oil to Teeside1977 Gas to Emden
17
Bravo blow-out
1977
December 20, 201918
Alexander L. Kielland disaster
1980
Seabed Subsidence in the Greater Ekofisk Area
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2/4-T
1974 1985 2006
B A
Seabed subsidence of2-2,5 meters observed
Jacking up of 6 steel platforms on the fieldcenter in 1987
Protective wall installed at the processingunit in 1988.
Consequence of Seabed Subsidence
20
December 20, 201921
Greater Ekofisk Area – Preparing for a Long Future
22
Ekofisk Area Production
Ekofisk:4,2 billion BOE
Other: 0,8 billion BOE
Eldfisk: 1 billion BOE
Cumulativeproduction6 billion BOE’s
>1000wells drillled
BOE pr day
EkofiskGrowth
Discovery
Ekofisk test production
Permanent Installations
Ekofisk ComplexJacking
EkofiskWater injection pilot
Ekofisk Waterflood Start EkofiskSouth
Ekofisk II
23
Total value creation – Greater Ekofisk Area 1969 – 2018
Total Value
Creation from the
Greater Ekofisk Area
amounts to NOK
2424 billion*
110 billion NOKEmployees
44 billion NOKLenders
Owners
245 billion NOK
Goods and services
859 billion NOK
Taxes and fees
1166 billion NOK
* Stated in 2018 NOK value/ Real 2018 NOK
24
Ekofisk – Fractured Chalk Reservoir
“White”
Fractured
Highly porous
Soft
Tight
25
Chalk Exposures – French Coast
26
Chalk - SEM images
27
Fractures
Person for scale
~3000m
~70m
~11 km
~5 km
~300m reservoir thickness
Ekofisk Field
28
December 20, 201929
Ekofisk Oil Production History
EkofiskGrowth
Discovery
Ekofisk test production
Permanent Installations
Ekofisk ComplexJacking
EkofiskWater injectionpilot Ekofisk Waterflood Start Ekofisk
South
Ekofisk II
December 20, 201930
Waterflood Evaluations – What’s the big deal?
1987 • Few, if any, waterfloods in fracturedchalk
• Will water prematurelybreakthrough?
• Will matrix imbibe water?
• What happens when we put water on chalk?
• Sustained acceptable injectivity?
Pilot testing
Waterflood Efficiency
Initial Water
Residual hydrocarbon
Initial Water
Imbibed water
Imbibed water
Residual hydrocarbon
Initial Water
Imbibed water
Residualhydrocarbon
Laboratory experiments initiated late 1970’s
Only Tor formation showed waterflood potential
Upper Ekofisk fm Lower Ekofisk fm Tor fm
December 20, 201932
Water injection1987 Field testing
- Multi year injection/production testing- Evaluate large scale recovery efficiency- Evaluate operational risk
Project sanctioned- Significant infrastructure investment- Viewed as high risk- Authorities and owners cooperated to reduce project value risk- Phased development
December 20, 201933
Ekofisk Waterflood
• Water injection capacity increased from 350,000 to 850,000 bwpd
• Number of injection well slots increased from 30 to 50
• More than 5 billion barrels of water injected
December 20, 201934
Ekofisk Waterflood – Main Enabler for Increased Recovery
EkofiskGrowth
Discovery
Ekofisk test production
Permanent Installations
Ekofisk ComplexJacking
EkofiskWater injectionpilot Ekofisk Waterflood Start Ekofisk
South
Ekofisk II
Depletion path?
December 20, 201935
Reservoir Compaction – Introducing Water Weakens Chalk
C11A
December 20, 201936
Ekofisk Field Management
Reservoir Pressure
Water Injection Rate
Seabed Subsidence Rate
December 20, 201937
Joint Chalk Research Program – 1985 to 2010
• Unknown geological territory
• Limited analog experiences
• Real challenge to effectivelyproduce
• Large resource base
• Low projected recoveryfactors
• Initiated by NPD and DEA -Norway and Denmarkknowledge share
• Improve geologicalunderstanding
• Wellcompletions/stimulations
• Wellbore stability
• EOR – water and gas injectionefficiency etc
• Geomechanical behavior ofchalk
• Fracture characterization
• Sponsored by chalk operators and license owners
• Total spend – 100 mmnok
• Research performed by
• Academia
• Commercial laboratories
• Company laboratories
• Company staff
Why What Who
17% 52%44%Ekofisk
Initial Assumption
Current plan
15% 33%26% ?Eldfisk
• Infill drilling
Significant Remaining Resource Potential
?
38
Oil In PlaceProduced
Increasing the Recovery Factor
6,7 B STB
2.8 B STB
Note: Arrows on Ekofisk and Eldfisk do not account for the relative size of the fields
Remaining Potential
(Movable Oil)
• EOR ?
• Optimize waterfloods
December 20, 201939
Permanent seismic cables over the Ekofisk reservoir
• Optical system installed in 2010
• 4000 receivers
• 98.8 % of sensor stations still active
• 17 surveys acquired so far
December 20, 201940
4D Seismics – Monitoring Injection Fronts to Locate Bypassed Oil
2011 2018 4D Differences Upper Ekofisk Water Front Mapping
Large change
No change
41
EOR – Continued Efforts
Gas Injection
Water Injection ✓
N2 Injection
EOR Screening
Air Injection
HC WAG
CO2
Smart Water ✓
CEOR (surfactant)
Studies Pilot Execution
GEA PAR Pre-Read - Confidential
Recent focus on
• Water additives for residual oil reduction
• Adjust water composition
42
Thank You
500,000 barrels of water per day
Offshore
Three fields in production900-1000 people
175,000 barrels of oil equivalentper day (gross)
Production
Water injection
ConocoPhillips 35.1 %Total 39.9 %
Vår 12.4 %Equinor 7.6 %
Petoro 5.0 %
Ownership in PL018