Building & Expanding the Ula...
Transcript of Building & Expanding the Ula...
Building & Expanding the Ula WAG
DEVEX, 13 May 2010 Sigrun Mellemstrand, Eirik Espe, Becki van Gestel, Masoud Haajizadeh, Simon Thomas, Ingrid E.I. Øxnevad BP Norge AS
2
Ula Field
• Overview
• Field History
• Current WAG Scheme
• Future WAG Scheme
• Summary
Overview Field History Future WAG Summary
Ekofisk
Tambar
ULA
Gyda
A b e r d e e n
S t a v a n g e r
L o n d o n
U l a E k o f i s k
E m d e n T e e s i d e
Current WAG
ULA
3
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
• Oselvar tie-in: 2011
• STOOIP
− ~1 billion stb (160 mill Sm3)
• Produced as of 01-01-10
− 440 mmstb oil (70 mill Sm3)
ULA
TAMBAR
Living Q
Drilling Production
BLANE
Overview Field History Future WAG Summary Current WAG
Blane Tambar
4
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 Summary Current WAG
5
• oAPI ~ 40 • T res ~295o F (146o C) • Pb ~ 2300 psi (159 bar) • P init ~ 7100 psi (490 bar) • P res ~ 6300 psi (434 bar) • MMP ~ 5000 psi (345 bar) • GOR ~ 500 scf/stb (89 m3/m3) • Visco ~ 0.35 cp • Viscw ~ 0.33 cp • Bo ~ 1.36 rb/stb (@Pb) • C1 in Injection Gas ~ 68%
Ula Fluids
Satu
ratio
n
1 0
Fractional Distance
Ula Gas and Oil saturations
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
1
0 100 200 300 400 500 600 700 800 900 1000
Distance from injector, ft
Ula Gas and Oil Density
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
1
0 200 400 600 800 1000
Distance from injector, ft
g/cm
3
Ula Slim Tube Simulation - Vaporizing Drive
1 0
0 1
500 grid blocks100 grid blocks 20 grid blocks
Den
sity
gr/c
c
oil
gas
Impact of Grid Size on Distributions of Phase Saturation and Density at 0.5 PVI
oil
gas
Miscible WAG Works Well in Ula • High SORW (35 - 50%) • Under-saturated oil • Pres: 6300 > MMP: 5000 psi
Overview Field History Future WAG Summary Current WAG
6
Reservoir Units
~ 10
0 m
Ula
Fo
rmat
ion
Perm (mD)
Upper Jurassic, shallow marine sandstones
Baffle between Unit 1A2 & 1A3
Capable of holding
>1000 psi (70 bar)
<5cm
Current WAG
Unit 1 Hor.
Producers
Unit 3 WAG
Injectors
1A11A21A31B
1-101-202-255-100
3
20-4000
20-200
10-100
2
2-15
4390
4400
4410
4420
4430
4440
4450
4460
4470
4480
4490
4500
DEPTH
METRES
3500
3510
3520
3530
3540
3550
3560
TVD
METRES
SW_2V/V1 0
Fluids A16A Initial After WF Future
Sorw ~ 35-50%
Sorm ~ 5-10%
Water
Gas/Water
Oil
Ula Stratigraphy Overview Field History Future WAG Summary Current WAG
Baffle in lower Unit 2
Capable of holding >35 psi
7
0.0
20000.0
40000.0
60000.0
80000.0
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
00.5
11.5
22.5
33.5
4
0.050000.0100000.0150000.0200000.0250000.0
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
00.10.20.30.40.50.60.70.80.91
020406080100120140
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
WCUT
WI s
tart
s
WA
G s
tart
s
Tam
bar
tie
d-in
Mor
e W
AG
co
nver
sion
s
Onl
ine
10
year
s af
ter
disc
over
y
arrested decline
WA
G o
il in
all
W
AG
pr
oduc
ers
Uni
t 1
prod
uctio
n st
arts
Sha
rp d
eclin
e
WA
G S
tudi
es
140 0
250 0
80 0
1 0
Oil Rate mbd
WI Rate mbd
GI Rate mmscfd GOR scf/stb
Ula Historical Profiles Overview Field History Future WAG Summary Current WAG
0.0
20000.0
40000.0
60000.0
80000.0
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
00.5
11.5
22.5
33.5
4
3600 0
Firs
t dee
p ho
rizon
tal
inje
ctor
Production increase
Beh
ind
flood
-fro
nt c
ore
8
• Appropriate water handling capacity à upgraded in 1992 and 1994
• Reservoir pressure above minimum miscibility pressure (~5000 psi / 345 bar)
• Appropriate gas handling capacity à 120 mmscfd gas processing (3.4 mill Sm3)
• Gas compression à installed in 1993-1994 for gas lift
• Gas supply à Re-inject gas after export route via Cod Field lost. Tambar, Blane and Oselvar tie-in.
• Conversion of water injectors to gas (WAG) 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
Prod
uction
& in
jection
0
1000
2000
3000
4000
5000
6000
7000
8000
Res
ervo
ir Press
ure
Injected Water, bpdProduced Water, bpdReservoir Pres s ure, ps i
Requirements to build the Ula WAG Overview Field History Future WAG Summary Current WAG
9
WAG Injector Water injector Unit 1 Producer WAG Producer
A04
A09A
A13A
A07C
A17B A15A
A18
A12A
Current WAG Scheme
• 3 vertical WAG producers up-dip − 1 shut-in
• 3 vertical WAG injectors down-dip − 1st injector converted in 1997 − 3 additional injectors in 2001/ 2002 following
Tambar tie-in − New WAG injector behind WAG flood front (A09A)
in 2006 • 1 horizontal WAG injector in Unit 3 • 1 vertical water injector down-dip
− Integrity problems with gas injection • Current injection capacity
− Gas handling: 120 mmscf/d gas (3.4 mill Sm3) − Gas injection: 90 mmscf/d gas (2.5 mill Sm3),
limited by wells − Water handling: 160,000 bbl/d water (25,400 Sm3) − Water injection: 50,000 bbl/d water (11000 Sm3),
limited by injection pump
Ula Top Structure Map
Overview Field History Future WAG Summary Current WAG
10
Ula WAG Sectors
• Large sectors (1km – 2.5 km)
• Sectors identified through tracer program
− 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
• 3 tracer injections in 2010
Overview Field History Future WAG Summary Current WAG
Waterflood sectors
WAG sectors 50/22 Tracer travel time, months
11
02468
1012141618
1996
1998
2000
2002
2004
2006
2008
2010
Oil rate (mstb/d)
0
2
4
6
8
10
1994
1996
1998
2000
2002
2004
2006
2008
2010
Oil Rate mstb/d)
0
2
4
6
8
10
1999
2001
2003
2005
2007
2009
Oil rate (mstb/d)
N
A18
A15/A15A
A12A
(~1600 m3/d)
WAG Works in Ula
• Historically 5-10 mbd of WAG oil (800-1600 Sm3/d)
− 25-50% of Ula production
• Currently ~20 mbd WAG oil, ~60-70 % of Ula production
• Total WAG oil: ~18 mmstb (2.9 mill Sm3)
• Current scheme, including the contracted Oselvar gas, will recover over 7% of STOOIP
Overview Field History Future WAG Summary Current WAG
12
Ula Gas Injection
• 128 bscf of injected gas (3.6 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
− New injectors target Unit 3
Overview Field History Future WAG Summary Current WAG
WAG Efficiency:
~7 mscf gas / bbl oil
(~0.8 Sm3 oil / kSm3 gas) 10
20
30
40
50
60
70
80
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
Gas
Injection, m
msc
fd
A13A: 39 bcfA09A: 14 bcfA07C : 36 bcfA04: 11 bcfA03A: 24 bcf
WAG InjectorWater injectorUnit 1 ProducerWAG ProducerWAG Sector
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG InjectorWater injectorUnit 1 ProducerWAG ProducerWAG Sector
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG InjectorWater injectorUnit 1 ProducerWAG ProducerWAG Sector
WAG InjectorWater injectorUnit 1 ProducerWAG ProducerWAG Sector
A15A
A18
A12A
A15A
A18
A12A
A04A04
A09A
A13A
A07C
A09AA09A
A13A
A07C
A17BA17B
13
2009 Drilling Campaign
• A-12A recompleted. Came online in June 2009, with higher oil rate than expected, and very high GOR.
• A-15A redrilled close to original A-15, online in November 2009.
− High initial production rates.
− Accumulation of mobilized oil
Overview Field History Future WAG Summary Current WAG
A12A oil rate and GOR from well tests
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
Jan-99 Jan-01 Jan-03 Jan-05 Jan-07 Jan-09
Oil
Rat
e [s
tb/d
], gr
een
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
GO
R [s
cf/b
bl],
red
Oil rateGOR
WAG effect from A07C
DHSV repair
TTAC
A15 oil rate and GOR from well tests
0
2000
4000
6000
8000
10000
12000
14000
16000
18000
Jan-96 Jan-98 Jan-00 Jan-02 Jan-04 Jan-06 Jan-08 Jan-10
Oil
Rat
e [s
tb/d
], g
reen
0
1000
2000
3000
4000
5000
6000
7000
8000
GO
R [s
cf/b
bl],
red
Oil rateGOR
WAG effect from A13A
WAG effect from A03A
Recompletion
DHSV failure
14
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.02
01.m
ar.0
218
.apr
.02
21.ju
n.02
11.se
p.02
04.d
es.0
202
.feb.
0315
.mar
.03
07.m
ai.03
18.ju
n.03
19.ju
l.03
03.se
p.03
09.o
kt.03
15.n
ov.0
327
.des
.03
05.fe
b.04
13.m
ar.0
413
.apr
.04
05.m
ai.04
09.ju
n.04
22.ju
l.04
25.se
p.04
05.n
ov.0
423
.des
.04
03.fe
b.05
17.m
ar.0
530
.apr
.05
09.ju
n.05
21.ju
l.05
14.se
p.05
26.o
kt.05
08.d
es.0
528
.jan.
0611
.mar
.06
20.a
pr.0
631
.mai.
0629
.jul.0
609
.sep.
0620
.okt.
0610
.des
.06
Date
wate
rcut
(vol
%)
watercut
A12A WC
Overview Field History Future WAG Summary Current WAG
15
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A15A
A18
A12A
A04A04
A09A
A13A
A07C
A09AA09A
A13A
A07C
A17BA17B
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 Analysis
30cm20cm 20cm15cm 15cm30cm20cm 20cm15cm 15cm
Overview Field History Future WAG Summary Current WAG
16
Moving to Expanded WAG (XWAG)
• Successful current WAG scheme in Ula
− Clear indication of mobilized oil production
− ~ 18 mmstb incremental oil produced
• Extensive data acquisition in A09A to evaluate effectiveness of WAG
− Clear indication of reduction of Sor
Current WAG
Overview Field History Future WAG Summary Current WAG
Expanded WAG
• Simulation studies on Expanded WAG
− Indicate potential for a healthy additional incremental recovery
− Maximize recovery with Unit 3 horizontal injectors
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG18
WAG16
WAG15
WAG8
WAG13
WAG1
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A15A
A18
A12A
A04A04
A09A
A13A
A07C
A09AA09A
A13A
A07C
A17BA17B
WAG18
WAG16
WAG15
WAG8
WAG13
WAG1
WAG InjectorWater injectorUnit 1 ProducerWAG ProducerWAG Sector
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG InjectorWater injectorUnit 1 ProducerWAG ProducerWAG Sector
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG InjectorWater injectorUnit 1 ProducerWAG ProducerWAG Sector
WAG InjectorWater injectorUnit 1 ProducerWAG ProducerWAG Sector
A15A
A18
A12A
A15A
A18
A12A
A04A04
A09A
A13A
A07C
A09AA09A
A13A
A07C
A17BA17B
17
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
S uspended 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 7WAG 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 s ingle 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
S uspended 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 7WAG 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 s ingle well cases , constant gas injection of 60 mmscfd
25 XWAG targets screened and ranked according to recoverable resources
Overview Field History Future WAG Summary Current WAG
7 XWAG targets chosen for recoverable resources, and location (sweep)
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG18
WAG16
WAG15
WAG8
WAG13
WAG1
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A15A
A18
A12A
A04A04
A09A
A13A
A07C
A09AA09A
A13A
A07C
A17BA17B
WAG18
WAG16
WAG15
WAG8
WAG13
WAG1
2 XWAG targets chosen for recoverable resources, location, drillability from existing slots, & good geologic understanding
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG16
WAG14
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A15A
A18
A12A
A04A04
A09A
A13A
A07C
A09AA09A
A13A
A07C
A17BA17B
WAG16
WAG14
18
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 à 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 à 140,000 bbls/d (22k Sm3/d)
• 2008: Commitment to purchase Oselvar gas volumes from 2011
• 2009: Bring back 2 WAG Producers
• 2010: First XWAG type well drilled Blane
Tambar MPP
Tambar East
Tambar Base
Oselvar
Future gas for Ula WAG Scheme:
>150 bcf
Overview Field History Future WAG Summary Current WAG
19
XWAG Plans Overview Field History Future WAG Summary Current WAG
2013
-201
9 • Potential for 5 more horizontal injectors − Install new wellhead platform
− Continue injection in Unit 3 with long, horizontal wells
2019
+
• 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
2009
-201
2
• 2 new horizontal injectors in Unit 3 (2010&2012)
− Target deeper injection in Unit 3
− Long, horizontal injectors ~1000m with passive downhole flow control & isolation packers for uniform injection
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG16
WAG14
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A15A
A18
A12A
A04A04
A09A
A13A
A07C
A09AA09A
A13A
A07C
A17BA17B
WAG16
WAG14
20
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 Summary Current WAG
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG18
WAG16
WAG15
WAG8
WAG13
WAG1
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A04
A09A
A13A
A07C
A17B
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
WAG InjectorWater injectorUnit 1 ProducerWAG Producer
A15A
A18
A12A
A15A
A18
A12A
A04A04
A09A
A13A
A07C
A09AA09A
A13A
A07C
A17BA17B
WAG18
WAG16
WAG15
WAG8
WAG13
WAG1
21
Summary
• Ula forms a strategic hub in the Norwegian North Sea
− Successful tie-ins of Tambar, Blane, tie-in of Oselvar in 2011
• 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
Overview Field History Future WAG Summary Current WAG
0
140
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
2008
2009
2010
WI GI/WAG
arrested decline
Acknowledgements
Thanks to BP Norge AS and DONG E&P Norge AS for allowing this information to be shared. Thanks the Ula team, Eirik Espe, Becki van Gestel, Masoud Haajizadeh, Simon Thomas, Ingrid E.I. Øxnevad