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19 October 2010CEP#1
Combining Offshore EOR and CCS in Denmark
IEA Offshore EOR Symposium
20th October 2010
Nigel Jenvey, Director, EOR Project Manager
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Slide no. 2 19 October 2010
Maersk is a global conglomerate that has existed for more than a hundred years
…with more than 117,000 employees worldwide
Maersk is an international company recognised for its activities
within shipping, energy, offshore, retail and industry
19 October 2010#3
The Importance of EOR to Maersk Oil
• Significant incremental production potential in Denmark
• Breaking new ground in our pursuit for reserves
• Pivotal role in supporting late life assets to increase
commercial recovery
• Technical and commercial challenges to overcome
There are many technically applicable EOR
technologies, but very few are
commercially applied…
19 October 2010#4
Maersk Oil EOR Related Experience – DUC Gas Injection
• Tyra gas injection (since 1987)
• Gorm crestal gas injection into the gas cap (1982-1994)
• Tyra gas injection into the oil rim (1999)
Gas Breakthrough in Two Months
( Injector to Producer 1000 feet )
Tyra Gas Injection Test
0
10
20
30
40
50
60
Jan-99 Jan-99 Mar-99 Apr-99 May-99 Jun-99 Jul-99 Aug-99 Sep-99 Oct-99 Nov-99 Dec-99 Jan-00 Feb-00 Mar-00 Apr-00 May-00 Jun-00
Gas R
ate
mm
scfd
twc-21a-gas production
twc-10 gas injection
19 October 2010#5
Maersk Oil EOR Related Experience – Qatar WAG Pilot
Source: IPTC-13327
Well 6
Well 5
• 6 month lean gas injection test (2008)
• Evaluate gas breakthrough and post-injection
water injectivity
19 October 2010#6
Maersk Oil EOR Related Experience – Algeria WAG Pilot
• October 2003-December 2006
• WAG injection well, with dedicated
updip monitor well 160m away
• Immiscible and miscible gas injection
cycles
• Evaluate target oil and injectivity
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Slide no. 7 19 October 2010
The Time for EOR is Now for Denmark
Source: DEA
19 October 2010#8
DUC Infrastructure
• 50 platforms
• 1 subsea completion
• 65 pipelines – approx. 800km
• 182 oil production wells
• 68 gas production wells
• 17 gas injection wells
• 94 water injection wells
• Some 700 onshore employees
• Some 500 offshore employees and 1000 contractors
19 October 2010#9
Remaining, 71%
DUC Field Recovery
• Residual oil• Thin oil columns• Bypassed oil• etc
Potential IOR and EOR, ?%
Scope Production, 4%
Produced, 19%
Remaining Production, 6%
Remaining, ?%
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Slide no. 10 19 October 2010
Dan Field Location
19 October 2010#11
Dan Field Production
0
5.000
10.000
15.000
20.000
25.000
30.000
35.000
40.000
45.000
50.000
55.000
60.000
65.000
70.000
75.000
80.000
85.000
90.000
95.000
100.000
105.000
110.000
115.000
120.000
125.000
130.000
135.000
140.000
Jan-7
0
Jan-7
3
Jan-7
6
Jan-7
9
Jan-8
2
Jan-8
5
Jan-8
8
Jan-9
1
Jan-9
4
Jan-9
7
Jan-0
0
Jan-0
3
Jan-0
6
Jan-0
9
Jan-1
2
Jan-1
5
Date
Prod
ucti
on
, B
OP
D
Depletion Waterflood
Actual Forecast
19 October 2010#12
Dan Field Development
2 KM
19 October 2010#13
2 KM
Halfdan
Seismic data indicates good areal sweep
19 October 2010#14
CO2 Sourcing Options
• Natural
• Industrial Processes (CO2 Capture)
• Gas Processing
• Refineries
• Manufacturing (cement, steel, fertilisers)
• Power
• Carbon Capture and Storage requires other funding mechanisms for implementation
$10/tonne
$30/tonne
$60/tonne
$90/tonne
19 October 2010#15
CCS Economics
Source: McKinsey
19 October 2010#16
Projected Growth of the new CCS industry
Source: IEA CCS Roadmap
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Slide no. 17 19 October 2010
• More than 750 million tonnes of CO2 are emitted annually from large
stationary sources relatively close to the North Sea
• Much of the North Sea geology is potentially suitable for CO2 storage, but
saline aquifers need exploration, appraisal and development
• Certain UK, Norwegian and Danish oil/gas fields are suitable for storage and
enhanced recovery techniques
Source: GESTCO
CO2 Storage Capacity
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Slide no. 18 19 October 2010
Not many sizeable CCS projects exist without EOR
Source: IPCC Special Report on CCS
How much CO2 storage capacity is
required for CCS when it is a „transitional‟
technology?
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Slide no. 19 19 October 2010
Worldwide EOR and CCS Potential
Source: Advanced Resources International
19 October 2010#20
CO2 Transport
• Today no ships transport industrial CO2 emissions
• CO2 Shipping can be cost competitive and is more flexible than
pipelines
• Maersk Tankers has designed a semi-pressurised/semi-fridgerated
20,000 m3 ship
• Interface with offshore discharge requirements key
Source: Yara
CO2 CAPTURE
CO2CO2
CO2 TRANSPORT
POWER
PLANT
CO2 OIL
CO2 INJECTION FOR STORAGE / EOR
19 October 2010#21
CO2 Transport
Semi-pressurized/
semi-refrigerated:
-55 degC and 6.5 bar
Underground Storage
100 - 300 bar
Fully-pressurized:
20 degC and 70-80 bar
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Slide no. 22 19 October 2010
Maersk Tankers’ 20,000 CBM CO2 Carrier
Source: HHI
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Slide no. 23 19 October 201023
1. Submerged Turret Off-Loading (STL) system
• Offloading under the ship
• Least exposure to weather/swell
• High installation costs*
Offshore CO2 Off-loading
• Offloading over the bow
• Highest exposure to weather/swell
• Lower installation costs*
2. Single Anchor Off-Loading (SAL) System
* The subsea system at the offshore field needs to be taken into consideration
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Slide no. 24 19 October 2010
A combination of an FSIU and CO2 carriers can be developed in the same way Maersk has developed its Floating Production Storage and Offloading (FPSO) logistics
• The ships are connected via a bow loading system and a stern discharge system
19 October 2010#25
Combining CCS and CO2 EOR
1. How to achieve a constant CO2 import rate?
• In-field phased development (aka “roll-the-flood” or “pattern-
by-pattern”)
• Alternative EOR/Storage field development
2. How to deal with different source timing/volumes?
• Phased development (aka “partial field expansion”)
• Pre-investment for full-field application
• Alternative EOR/Storage field development
• 2 key field development questions:
19 October 2010#26
Full-field CO2 EOR – an illustration
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
0 5 10 15 20 25 30
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
Waterflood CO2 Import (Falling)
Non-economic WF CO2 EOR
CO
2 Im
po
rt R
ate
, %
Oil P
rod
ucti
on
Rate
, %
Years
19 October 2010#27
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
0 5 10 15 20 25 30
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
CO
2 Im
po
rt R
ate
, %
Oil P
rod
ucti
on
Rate
, %
Phased CO2 EOR – an illustration
Years
Waterflood CO2 Import (Phsd/Cons)
Non-economic WF CO2 EOR Phasing
28
• Given miscibility, CO2 EOR recovery can vary due to 3 main reasons:
1. Conformance2. Target Oil3. Injectivity
• These can vary over any single field due to natural or man-made variations
• Reducing the uncertainty and calibrating forecasts is key to improve the quality of decision making, via:
– Field waterflood performance– Analogue field performance– Laboratory tests– Field tests
CO2 EOR – Recovery Uncertainty
0,0E+00
1,0E-07
2,0E-07
3,0E-07
4,0E-07
5,0E-07
6,0E-07
7,0E-07
0 2 4 6 8 10 12 14Time after injection in FA-11 (d)
Co
ncen
trati
on
(g
/l)
FA-11 2-FBA
FF-07 4-FBA
FA-01B 3,4-DFBA
FB-23 2,6-DFBA
FE-07 2,4,5-TFBA
Source: DUC
29
Opportunity exists for new CO2 EOR
projects to be more efficient with recovery
given availability of lower cost CO2
CO2 EOR – Development Opportunities
30
Topsides33%
Brownfield29%
Wells38%
– Manifolds (production, test, injection, gas lift, original)
– Utilities (water injection, seawater lift, cooling/heating,
diesel, potable water, emergency power)
– Workovers (tubing change out, tie-back
casing, sidetracks)
– Gas lift modifications (CO2 contamination)
– Separation (2 stage production, test)
– Metering (oil, water, HC gas, CO2 import, CO2
injected, CO2 flared/vented, power)
– Gas processing(compression, pumping,
dehydration, vent, flare)
– Utilities (fuel gas, cooling/heating,
instrument air, N2, chemicals, hydraulics, drains, fire detection and supression)
– Pipelines
CO2 EOR – Implementation Costs
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Slide no. 31 19 October 2010
Dan Facilities
FF
FG
FC
FD
FB
FA
FE
To Tyra EastTo Gorm
To/From Halfdan HDA
From Halfdan HBB
From Kraka
E
C
B
AD
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Slide no. 32 19 October 2010
CO2 Development on Dan
FF
FG
FC
FD
FB
FA
FE
To Tyra EastTo Gorm
To/From Halfdan HDA
From Halfdan HBB
From Kraka
E
C
B
AD
Scope on FE:• CO2 Injection Manifold• CO2 Production Manifold• CO2 Test Manifold
Scope on FA:• CO2 Injection Manifold• CO2 Production Manifold• CO2 Test Manifold
Utilities from F Complex:• Water Injection• Produced Water• Seawater lift• Cooling medium• Diesel• Potable Water• Main Power• Emergency Power
Scope on FB:• CO2 Injection Manifold• CO2 Production Manifold• CO2 Test Manifold
Scope on FF:• CO2 Injection Manifold• CO2 Production Manifold• CO2 Test Manifold
Scope on A & D:• CO2 Injection Manifold• CO2 Production Manifold• CO2 Test Manifold
Scope on New Deck:• 2 stage separation• Test separator• Crude metering, export• LP compression• Injection compression• Import CO2 pumping• TEG Dehydration• Fuel gas• Seawater lift
• Cooling medium• Instrument Air• Nitrogen• Chemical injection• HPU skid• HP, LP, Atmos vent• Closed/HO/NHO drains• Firewater
33
CO2 EOR – CCS Verification
2. Monitoring – of the injection facilities, the storage complex, and where appropriate the surrounding environment
• Potential requirements for projects under the EU CCS Directive:
Source: IPCC
Source: Environmental Geology, Springer
1. Site Characterisation – to ensure no significant risk of leakage, environmental damage or health impact
3. Abandonment – to allow the transfer of responsibility
34
EOR is an enabling commercial step towards constructing an infrastructure that can handle CO2 emissions from Northern Europe
CENS was the 1st industry project in 2001Original concept proposed a main CO2 pipeline
infrastructure in the North Sea capable of transporting more than 30mtCO2/yr
Adapted to be a phased development
Courtesy: CO2 Global
CO2 EOR – North Sea Network
35
What are we doing about it?
• Assessing the potential commercial application of CO2 EOR linked with CCS
– EU co-funded (NER300) CCS project timeline
Now 2011 2012 2013 2014 2015
Expre
ssio
n o
f in
volv
em
ent
EU
Fundin
g
application
EU
Fundin
g
announcem
ent
CO
2In
jection
FEED Construction
Possib
le I
nj
Test
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• CO2 EOR may become a viable technique to increase recovery and extend the field life of certain DUC fields.
• To enable this, given the current risks/costs of implementation, EOR in combination with CO2 Storage is being persued to mature a commercial opportunity
• This will require phasing of the EOR flood:
– To maintain a constant CO2 import rate, given CO2 recycling
– Due to the available CO2 volumes initially from CCS demo projects
• Subject to initial successful standalone CO2 EOR/Storage field implementation, further implementation may be possible in other DUC fields and thereby mitigate the impacts of continued oil production decline
Summary
Thank you
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