sleipner · sleipner knowledge sharing in ccs projects - workshop mobile, alabama sveinung hagen...

Sleipner Knowledge sharing in CCS projects - Workshop Mobile, Alabama Sveinung Hagen and colleagues - Statoil May 16 and 17 – 2012

Talk Outline and Context

Sleipner

In Salah

Snøhvit LNG

1996- 2004- 2008- 2012- ?

Mongstad Full-scale

Test Centre Mongstad

Statoil’s CCS projects An Industrial Approach to the Climate Change Challenge

• Storage operations overview

• Sleipner background

• Technology used and outcomes

• Lessons learned

Overview Sleipner Background Technology used and… Lessons learned

Snøhvit

Sleipner In Salah

0

1

2

Dep

th (k

m)

Diverse Storage Experience

• Offshore/onshore • Shallow/deep • Horizontal/vertical wells • High/low por-perm parameters

Eiken et al. 2011


Sleipner CO2 injection site - Location

• CO2 from the Sleipner field is stored in the Utsira Formation, North Sea

• Reservoir unit at 800-1100 m depth

• One CO2 injector - 36 meter perforation at ~1012 meter (TVD)

• Injected gas is ~98% CO2

• 13,5Mt CO2 have been injected (as of May 2012, ~0,9M per annum)

CO2 Plume outline


The Sleipner Vest Field - Key Characteristics

• Largest gas/condensate field in the Sleipner area (North Sea), on stream in 1996

• Partners: Statoil - operator (58,35 %), ExxonMobil* (32,24 %), Total** (9,41 %)

• Higher CO2 content (4-9%) than the gas export quality specification allows (2,5%)

• Capture absorption at 100 bar, 60-80ºC, Amine 45wt% MDEA

• Decision to store geologically the captured CO2 was based on willingness to try

out new technology and the CO2 tax incentive

• Sleipner CCS is an internationally-recognised benchmark project

* ExxonMobil Exploration & Production Norway AS ** Total Norge AS


The Utsira Formation 0 150

GR TVD (m)

850

900

950

1000

1050

DT 240 40

Net/gross: 0.98 Porosity: 35-40 % Permeability > 1 Darcy ~ 200 m thick

Top Utsira TWT


-40 -20 0 20 40 60 80 100

Temperature [oC]

Pre

ssur

e [b

ar]

10

100

10

00

1

0000

liquid

vapour

solid

Phase Behaviour at Operating Conditions


Operating the Sleipner CO2 Project Operational Performance

• Stable wellhead pressure ~65bar • Wellhead temperature held at 25oC

Monitoring Data • Wellhead pressure and flow rate is monitored

continuously • Gas composition samples are taken intermittently • Seven time-lapse (4D) seismic surveys • Two repeat gravimetric surveys • Electromagnetic survey • Seabed surveys (2006 & 2011)

Key subsurface uncertainties • Role of internal Utsira shale layers, plume propagation • Reservoir and wellbore processes • Maximum injection capacity (rate)


Cumulative CO2 injection to date

0123456789

1011121314

1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013

Acc

umul

ated

inje

cted

CO

2 [m

illio

n to

ns]

Year

Gravity surveys

Seismic surveys

Seafloor mapping

CSEM survey

CO2 Injection rate ~0.9Mtpa

Baseline seismic survey in 1994

Seven repeats thereafter


Sleipner CO2 Time-lapse Seismic Data

1994 2001

2008 2008-1994

Layer 9

Injection at 1010-1013 meter depth (TVD)


Sleipner Movie


1999 2001 2002 2004 2006 2008 1 km

Top Utsira Formation (TWT) All layers

Incr

easi

ng a

mpl

itude

Sleipner CO2 seismic monitoring (Alternative if movie does not work)

855

910

Tim

e [m

s]

Injection point


Gravimetric monitoring

*Alnes et al. 2010

• CO2 displacing water causes a negative change in the gravity field

• Temperature measurements imply an average density from 705 to 675 kg/m3

• Gravimetric measurements constrains the in-situ CO2 density to 720 +/- 80 kg/m3

‒ Seismic data is used for geometry definition

• This suggests a maximum dissolution rate of 1.8% per year*


Other monitoring at Sleipner

• Seabed surveys in 2006 - side scan sonar and multi beam echosounding

• Synthetic Aperture sonar 2011 from Autonomous Underwater Vehicle (AUV)

• CSEM survey also done (no clear signal interpretable so far)

• Visual observations of the seafloor (ROV), no gas bubbles observed


Lessons learned • Geophysical, non-invasive monitoring at Sleipner has been extremely valuable and

has been used to address most of the operational questions

• Down hole gauges, which are now available in the industry, would have improved the accuracy to constrain temperature/pressure

• Improved understanding of fluid dynamic processes (CO2 brine) has resulted from the Sleipner pioneering case (sharing of data has improved this)

• Detailed geological features controls the CO2 distribution and are difficult to predict in advance


References • Alnes, H., Eiken, O., Nooner, S., Sasagawa, G., Stenvold, T. and Zumberge, M., 2010. Results from Sleipner gravity

monitoring: updated density and temperature distribution of the CO2 plume. 10th International Conference on Greenhouse Gas Technologies, 19-23 Sept. 2010, Amsterdam, Netherlands. www.sciencedirect.com

• Eiken, O., Ringrose, P., Hermanrud, C., Nazarian, B. & Torp, T., 2011. Lessons learned from 14 years of CCS Operations: Sleipner, In Salah and Snøhvit. 10th International Conference on Greenhouse Gas Technologies. Energy Procedia, Volume 4, 5541-5548.

• Hansen, H., Eiken O., Aasum T. O., 2005. Tracing the path of carbon dioxide from a gas-condensate reservoir, through the amine plant and back into a subsurface aquifer. Case study: The Sleipner area, Norwegian North Sea. Helga Hansen, Ola Eiken og Thor Olav Aasum. SPE 96742, 2005.

• Singh, V., Cavanagh, A., Hansen, H., Nazarian, B. Iding, M. and Ringrose, P., 2010. Reservoir modeling of CO2 plume behavior calibrated against monitoring data from Sleipner, Norway. SPE paper 134891 presented at the SPE Annual Technical Conference and Exhibition held in Florence, Italy, 19–22 September 2010

http://www.sciencedirect.com/

Sveinung Hagen Leader - CO2 Storage Exploration [email protected], tel: +47 41 51 37 06 www.statoil.com

Thank you

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