building & expanding the ula wag
DESCRIPTION
Building & Expanding the Ula WAG. FORCE WAG Conference 18 March 2009 Becki van Gestel, BP Norge AS. S. t. a. v. a. n. g. e. r. U. l. a. A. b. e. r. d. e. e. n. E. k. o. f. i. s. k. T. e. e. s. i. d. e. E. m. d. e. n. L. o. n. d. o. n. Ula Field. - PowerPoint PPT PresentationTRANSCRIPT
Building & Expanding the Ula WAG
FORCE WAG Conference18 March 2009Becki van Gestel, BP Norge AS
Ula Field
• Overview
• Field History
• Current WAG Scheme
• Future WAG Scheme
• Summary
Overview Field History Future WAG Summary
Ekofisk
Tambar
ULA
Gyda
Aberdeen
Stavanger
London
Ula
Ekofisk
Emden
Teeside
Current WAG
Ula Facts
• Ula Ownership:
− 80% - BP (operator)
− 20% - DONG E&P Norge AS
• On stream: 1986
• Tambar Field tie-in: 2001
• Blane Field tie-in: 2007
• STOOIP
− ~1 billion stb (160 mill Sm3)
• Produced as of 01-01-09
− 436 mmstb oil (70 mill Sm3)
ULA
TAMBAR
Living Q
DrillingProduction
BLANE
Overview Field History Future WAG SummaryCurrent WAG
Blane Tambar
Ula Structure
• Elongated four-way salt induced dip closure
• Reservoir dips between 0 and 10o
− Lower dips at the crest and to the south (0 to 5o)
• A NW-SE fault system bisects the structure
• Shallower oil-water contact in west flank
• Reservoir depth: 3350-3800m
TAMBAR
EF OWC - 3800m
NF OWC - 3560m
WF OWC - 3500m
NE
SW
NESW
Unit 1
Unit 2+3Triassic
3350
3500
3650
3800
3200
NESW
Unit 1
Unit 2+3Triassic
3350
3500
3650
3800
3200
Overview Field History Future WAG SummaryCurrent WAG
Reservoir Units
~ 1
00
m
Ula
F
orm
ati
on
Perm (mD)
Upper Jurassic, shallow marine sandstones
Baffle between
Unit 1A2 & 1A3
Capable of holding
>1000 psi (70 bar)
<5cm
CurrentWAG
Unit 1Hor.
Producers
FutureUnit 3WAG
Injectors
1A11A21A31B
1-10
1-20
2-25
5-100
3
20-4000
20-200
10-100
2
2-15
4390
4400
4410
4420
4430
4440
4450
4460
4470
4480
4490
4500
DE
PTH
ME
TR
ES
3500
3510
3520
3530
3540
3550
3560
TVD
ME
TR
ES
SW_2
V/V1 0
FluidsA16AInitial After WF Future
Sorw ~ 35-50%
Sorm ~ 5-10%
Wat
er
Gas
/Wat
er
Oil
Ula StratigraphyOverview Field History Future WAG SummaryCurrent WAG
Baffle in lower Unit 2
Capable of holding >35
psi
0.00.40.71.11.41.82.1
19
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WCUT
WI
sta
rts
WA
G
star
ts
Tam
bar
tie
d-in
Mor
e W
AG
conv
ersi
ons
Onl
ine
10
year
s af
ter
disc
over
y
arrested decline
WA
G o
il in
al
l W
AG
pr
oduc
ers
Un
it 1
p
rod
uct
ion
star
ts
Sha
rp d
eclin
e
WA
G S
tudi
es
140
0
250
0
60
0
1
0
2100
0
Oil Rate mbd
WI Rate mbd
GI Rate mmscfdGOR scf/stb
Ula Historical ProfilesOverview Field History Future WAG SummaryCurrent WAG
Requirements to build the Ula WAG
• Appropriate water handling capacity upgraded in 1992 and 1994
• Reservoir pressure above minimum miscibility pressure (~5000 psi / 345 bar)
• Appropriate gas handling capacity 60 mmscfd gas processing (1.7 mill Sm3)
• Gas compression installed in 1993-1994 for gas lift
• Gas supply Re-inject gas after export route via Cod Field lost, Tambar tie-in
• Conversion of water injectors to gas (and water) injectors
0
50000
100000
150000
200000
250000
Oct
-86
Oct
-88
Oct
-90
Oct
-92
Oct
-94
Oct
-96
Oct
-98
Oct
-00
Oct
-02
Oct
-04
Oct
-06
Oct
-08
Pro
duct
ion &
inje
ctio
n
0
1000
2000
3000
4000
5000
6000
7000
8000
Res
ervo
ir P
ress
ure
Injected Water, bpd
Produced Water, bpd
Reservoir Pressure, psi
Overview Field History Future WAG SummaryCurrent WAG
Current WAG Scheme
• 3 vertical WAG producers up-dip
• 4 vertical WAG injectors down-dip
− 1st injector (A03A) converted in 1997
− 3 additional injectors in 2001/ 2002 following Tambar tie-in
− New WAG injector behind WAG flood front (A09A) in 2006
• Current injection capacity
− 53 mmscf/d gas (1.5 mill Sm3)
− 70,000 bbl/d water (11000 Sm3)
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
A15
A18
A12A
A11
A03AA09A
A13A
A04
A07C
Ula Top Structure Map
Overview Field History Future WAG SummaryCurrent WAG
Ula WAG Sectors
• Large sectors (1km – 2.5 km)
• Sectors identified through tracer programme
− Originally with water tracers (waterflood sectors)
− Verified with gas tracers (WAG sectors)
• Initial breakthrough times
− Water: 11 to 55 months
− Gas: 15 to 35 months
Overview Field History Future WAG SummaryCurrent WAG
A-11
81/12/1515/37/88/23
50/22/2020/28/88/84/84
<8/30/3555
36
23
35
35/140/39/3131/40/40
73
27
66/140
11
54/22
3131/40/42
Waterflood sectors
WAG sectors
50/22
Tracer travel time, months
0
2
4
6
8
10
19
96
19
98
20
00
20
02
20
04
20
06
Oil rate (mbd)
0
2
4
6
8
10
19
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20
00
20
02
20
04
20
06
Oil rate (mbd)
0
2
4
6
8
10
19
96
19
98
20
00
20
02
20
04
20
06
Oil rate (mbd)
N
A18
A15
A12A
(~1600 m3/d)
WAG Works in Ula
• Historically 5-10 mbd of WAG oil (800-1600 Sm3/d)
− 25-50% of Ula production
• Total WAG oil: ~15 mmstb (2.2 mill Sm3)
• Current scheme will recover over 3% of STOOIP
Overview Field History Future WAG SummaryCurrent WAG
10
20
30
40
50
60
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
Gas
Inje
ctio
n, m
msc
fd
A13A: 35 bcf
A09A: 10 bcf
A07C: 31 bcf
A04: 11 bcf
A03A: 24 bcf
Ula Gas Injection
• 110 bscf of injected gas (3.1 bill Sm3)
− ~20% recycled gas
• WAG oil produced from all 4 sectors
− Indicated by gas tracer data and confirmed by well test results
• Limited sweep in lower perm Unit 3
− Verified by PLTs in injectors while on gas and water injection
Overview Field History Future WAG SummaryCurrent WAG
WAG Surveillance
Key to Evaluating Benefits of WAG
• Gas tracer injection and sampling
• PLT in injectors
• Weekly WC measurements
• Monthly well tests
• Continuous THP monitoring
• Injectivity
• WAG slug identification
• A09A core in mature WAG sector
• 4D seismic being evaluated
A03A PLT
3 injection
zones
W-12 (A12A)
60
65
70
75
80
85
90
95
02.ja
n.0
2
01.m
ar.02
18.a
pr.02
21.ju
n.0
2
11.s
ep.0
2
04.d
es.
02
02.feb.0
3
15.m
ar.03
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ai.0
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n.0
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19.ju
l.03
03.s
ep.0
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kt.0
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ov.
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es.
03
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4
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ar.04
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pr.04
05.m
ai.0
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n.0
4
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l.04
25.s
ep.0
4
05.n
ov.
04
23.d
es.
04
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5
17.m
ar.05
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pr.05
09.ju
n.0
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ep.0
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kt.0
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es.
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n.0
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ar.06
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pr.06
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ai.0
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l.06
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ep.0
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kt.0
6
10.d
es.
06
Date
wat
ercu
t (v
ol%
)
watercut
A12A WC
Overview Field History Future WAG SummaryCurrent WAG
Data acquisition behind WAG flood front
Extensive Data Acquisition Program in 2006
• A09A was drilled in a mature WAG sector
• Reservoir was cored & logged
− To evaluate effectiveness of current WAG scheme
− To quantify Sor distribution
• 101 meters of core (100% core recovery)
• Performed extensive study program
− Over 800 core plugs taken for analysis
− Routine core & fluid sample analysis
− Sw and GC, (well site and lab plugs)
− SCAL m & n, Rw from w/s plugs
− Log AnalysisCurrentWAG
Injector
ExistingWAG
Producer
Sorm from core
Sorw from core
A9A
A15
A3A
CurrentWAG
Injector
ExistingWAG
Producer
Sorm from core
Sorw from core
A9A
A15
A3A
30cm20cm 20cm15cm 15cm30cm20cm 20cm15cm 15cm
Overview Field History Future WAG SummaryCurrent WAG
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
A15
A18
A12A
A13A
A03AA09A
A04
A07C
A11
• Revealed 2 WAG tongues related to injection of gas in A03A• Consistent message from different data sources• Sorm and Sorw in line with previous SCAL data
Tongue 1Sorm~5-15%Sg~10-40%
Tongue 2Sorm~5-15%Sg~10-50%
G
G
FluidSamples
GR, PORGR, POR Kh, KvKh, Kv T, RwT, Rw So, SwSo, Sw NMR: SgNMR: Sg PNC: SgPNC: SgRCI: PRCI: P
Cn/C40Cn/C40
A09A WAG Observation OverviewOverview Field History Future WAG SummaryCurrent WAG
Moving to Expanded WAG (XWAG)
• Successful current WAG scheme in Ula
− Clear indication of mobilized oil production
− ~ 15 mmstb incremental oil produced
• Extensive data acquisition in A09A to evaluate effectiveness of WAG
− Clear indication of reduction of Sorm 10%
A02B
A01B
A14A
A10A A05B
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
A18
A12A
A13A
A03AA09A
A04
A07C
A11
A15
Current WAG
Overview Field History Future WAG SummaryCurrent WAG
A02B
A01B
A14A
A10A
A05B
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
A15
A18
A12A
A13A
A03AA09A
A04
A07C
A11
WAG14
WAG16
WAG8
WAG13
WAG1
WAG15
WAG18
Expanded WAG
• Extensive simulation studies on Expanded WAG
− Indicate potential for a healthy additional incremental recovery
− Maximize recovery with Unit 3 horizontal injectors
XWAG Screening
A-13A
A-3A
A-4
A-7C
A-10A
A-12A
A-14A
A-15
A-17A
A-18
A-1B
7/12-2
7/12-3
7/12-3A
7/12-4
7/12-6
7/12-7
7/12-8
7/12-9
A-1
A-10
A-12
A-13
A-14
A-16
A-16A
A-17
A-1A
A-2A
A-3
A-5
A-5A
A-7
A-7B
A-8
A-8AA-9
A-11
Legend
Oil Producer
Water Injector
WAG Injector
Suspended or Abandoned
Well trajectory
-3828 m ssl FWL
-3756 m ssl FWL
-3714 m ssl FWL
-3528 m ssl FWL
-3557 m ssl FWL
X-WAG Horisontal Injector
WAG 1
WAG 2
WAG 3
WAG 4
WAG 5
WAG 6
WAG 7
WAG 8
WAG 9
WAG 10
WAG 11
WAG 12
Possible pre-Producers.
WAG 13
WAG 14
WAG 15
WAG 16
WAG 17
WAG 18
Reserves by 2020 for single well cases, constant gas injection of 60 mmscfd
A-13A
A-3A
A-4
A-7C
A-10A
A-12A
A-14A
A-15
A-17A
A-18
A-1B
7/12-2
7/12-3
7/12-3A
7/12-4
7/12-6
7/12-7
7/12-8
7/12-9
A-1
A-10
A-12
A-13
A-14
A-16
A-16A
A-17
A-1A
A-2A
A-3
A-5
A-5A
A-7
A-7B
A-8
A-8AA-9
A-11
Legend
Oil Producer
Water Injector
WAG Injector
Suspended or Abandoned
Well trajectory
-3828 m ssl FWL
-3756 m ssl FWL
-3714 m ssl FWL
-3528 m ssl FWL
-3557 m ssl FWL
X-WAG Horisontal Injector
WAG 1
WAG 2
WAG 3
WAG 4
WAG 5
WAG 6
WAG 7
WAG 8
WAG 9
WAG 10
WAG 11
WAG 12
Possible pre-Producers.
WAG 13
WAG 14
WAG 15
WAG 16
WAG 17
WAG 18
Reserves by 2020 for single well cases, constant gas injection of 60 mmscfd
2 XWAG targets chosen for recoverable resources, location, drillability from existing slots, & good geologic understanding
A02B
A01B
A14A
A10A
A05B
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
A15
A18
A12A
A13A
A03AA09A
A04
A07C
A11
Ula top structure map
WAG14
WAG16
7 XWAG targets chosen for recoverable resources, and location (sweep)
A02B
A01B
A14A
A10A
A05B
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
A15
A18
A12A
A13A
A03AA09A
A04
A07C
A11
WAG14
WAG16
WAG8
WAG13
WAG1
WAG15
WAG18
25 XWAG targets screened and ranked according to recoverable resources
Overview Field History Future WAG SummaryCurrent WAG
XWAG Enablers
• 2006: A09A WAG injector drilled & cored behind flood front (10% Sorm)
• 2007-2008: Increase gas handling capacity with Ula Gas Upgrade (UGU)
− Gas handling 60 mmscfd 120 mmscfd (3.4 mill Sm3/d)
• 2007: Identify locations & slots for 2 new WAG injectors
• 2007-2008: Investigate passive downhole flow control for uniform injection in horizontal wells
• 2008-2010: Replace water injection pumps 140,000 bbls/d (22k Sm3/d)
• 2008: Commitment to purchase Oselvar gas volumes from 2011Blane
Tambar MPP
Tambar East
Tambar Base
Oselvar
Future gas for Ula WAG
Scheme: >150 bcf
Overview Field History Future WAG SummaryCurrent WAG
XWAG Plans
A02B
A01B
A14A
A10A
A05B
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
A15
A18
A12A
A13A
A03AA09A
A04
A07C
A11
WAG14
WAG16
WAG8
WAG13
WAG1
WAG15
WAG18
WAG14
WAG16
Overview Field History Future WAG SummaryCurrent WAG
20
13
-20
17 • Potential for 5 more horizontal
injectors
− Install new wellhead platform
− Continue injection in Unit 3 with long, horizontal wells
20
17
+
• Evaluate additional sources of gas for long term
• Full project has potential to increase recovery by ~10% of STOOIP
− Bring total recovery to ~70% through technology
• Enable Ula to produce past 2028
20
09
-20
12
• Plans for 2 new horizontal injectors in Unit 3 (WAG14 in 2009 & WAG16 in 2012)
− Target deeper injection in Unit 3
− Long, horizontal injectors ~1000m with passive downhole flow control for uniform injection
XWAG Challenges and Mitigations
• Commerciality - high early investment and late pay-back
− Project phasing
− 3rd Party tie-ins (Oselvar)
• Completion conformance
− Passive downhole flow control
− Evaluation of concept needed
• Reservoir response prediction
− Comprehensive uncertainty analysis to understand range of outcome
• Life of field surveillance plan
− Surveillance commitment
Overview Field History Future WAG SummaryCurrent WAG
A02B
A01B
A14A
A10A
A05B
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
WAG Injector
Water injector
Unit 1 Producer
WAG Producer
A15
A18
A12A
A13A
A03AA09A
A04
A07C
A11
WAG14
WAG16
WAG8
WAG13
WAG1
WAG15
WAG18
Summary
• Ula forms a strategic hub in the Norwegian North Sea
− Successful tie-ins of Tambar, Blane, and potentially Oselvar
• Miscible WAG is an effective process in Ula
− Clear indication of mobilized oil production from WAG producers
− Clear indication of reduced Sor (down to 10%) in WAG flooded zone from A09A core/log data
− Recovery increased and lifetime extended
• WAG Expansion will realize a healthy additional incremental recovery of ~10% STOOIP
− Enables production at current levels beyond license period of 2028
020406080
100120140
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
140
0Oil
Rat
e m
bd
arrested decline
0.00.40.71.11.41.82.1
19
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GI/WAGWI
Overview Field History Future WAG SummaryCurrent WAG
Questions?
Acknowledgements:Thanks to BP Norge AS and DONG E&P Norge AS for allowing this information to be shared.Thanks to Masoud Haajizadeh, Simon Thomas, Kevin Best, & Stijn de Jongh for contributions to slide material.