Feasibility of Reproduction of Stored CO2 from the Utsira Formation at the Sleipner Gas Field

Akervoll, Idar; Lindeberg, Erik; Lackner, Alf Sebastian

doi:10.1016/j.egypro.2009.02.020

Cited by 25 publications

(15 citation statements)

References 11 publications

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“…Images of the CO2 underground distribution should be taken sufficiently often in order to assess movement of the CO2 plume. Knowing where CO2 is located will facilitate remedy in case of leakage by, for example, producing CO2 and re-injecting it in another location (Akervoll et al 2009). In addition to seismic monitoring, further measures must be included in order to ensure maximum control over the storage site, such as analyses of ground water, soil gas, and air.…”

Section: Risk Of Leakage and Need For Monitoringmentioning

confidence: 99%

Use of low- and high-IFT fluid systems in experimental and numerical modelling of systems that mimic CO2 storage in deep saline formations

Polak

Cinar

Holt

et al. 2015

Journal of Petroleum Science and Engineering

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Section: Risk Of Leakage and Need For Monitoringmentioning

confidence: 99%

Use of low- and high-IFT fluid systems in experimental and numerical modelling of systems that mimic CO2 storage in deep saline formations

Polak

Cinar

Holt

et al. 2015

Journal of Petroleum Science and Engineering

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“…The estimated apparent anisotropy of the horizontal permeability due to topography is characterized by the ratio K MAX Up to now our interpretation was based on the assumption of a 1D-heterogeneous medium with the presence of a single vertical migration pathway. A possible alternate interpretation of the elongated shape of the CO 2 plume could be the presence of additional feeder channels spread along the elongation direction of the plume, as suggested in the reservoir simulation of Akervoll et al (2009). The reality could lie between these two explanations.…”

Section: D Geometry and Vertical Line Source Assumptionsmentioning

confidence: 90%

Estimation of permeability anisotropy using seismic inversion for the CO₂ geological storage site of Sleipner (North Sea)

Dubos-Sallée

Rasolofosaon

2011

GEOPHYSICS

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Since 1996, more than 11 Mt of CO 2 have been injected into a deep saline aquifer, the Utsira Sand formation, at the Norwegian Sleipner field. An unexpected application of the extensive seismic monitoring program over this field leads to the estimation of the depth dependence of the permeability anisotropy (strength and direction). Time-lapse seismic monitoring is used to follow the displacement of the injected CO 2 , considered as a permeability tracer. The upper half of the Utsira sand formation exhibits large anisotropy, with a ratio f between the maximum and minimum horizontal permeabilities larger than six. In contrast, f can be as small as two in the lower half. The direction of the maximum horizontal permeability does not exhibit substantial depth dependence and lies between N18 E and N34 E. This is in agreement with previous authors who pointed out a clear CO 2 plume structure markedly elongated in the north-northeast-south-southwest direction. The small topographical trap at the top of the Utsira sand formation is a minor extrinsic cause of the measured permeability anisotropy, compared to the intrinsic effect of the formation permeability. This permeability information is crucial for reservoir simulation and for forecasting of the CO 2 plume expansion for different scenarios of injection.

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“…Core measurement of residual CO 2 saturation from the unconsolidated Utsira Sand at the Sleipner CO 2 injection site gave values of CO 2 loss of ca. 25 % [26]. Applied to our modelling area, such a value would indicate a dissrate-factor of ca.…”

Section: Co 2 -Dissrate Factormentioning

confidence: 97%

“…The factor was calibrated versus migration distance simulated by reservoir models for Gassum Formation, Skagerrak area [25] and core measurement of residual CO 2 saturation (ca. 25 %) from the unconsolidated Utsira Sand at the Sleipner CO 2 injection site [26]. From this calibration, a dissrate-factor of 250 was used further in the basin modelling approach.…”

Section: Varying the Co 2 Dissolution Rate Factormentioning

confidence: 99%

CO2 Storage Modelling and Capacity Estimation for the Trøndelag Platform, Offshore Norway - using a Basin Modelling Approach

et al. 2014

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There are several approaches to estimate possible storage capacities for aquifers and traps in sedimentary basins, ranging from static theoretical capacities estimates to more detailed methods involving dynamic modelling. In this paper, we used a modified version of the basin modelling software SEMI [1, 2] which applies a ray tracing technique to migrate CO 2 within a carrier bed below a sealing cap-rock. We present a modelling strategy for a systematic modelling of maximum trap storage capacities and a mapping of possible "safe" injection localities for a storage unit. Two end-member models regarding the influence of faults were tested. The basin modelling results are compared and validated with results obtained from an reservoir simulation software.Simulations were carried out for the Trøndelag Platform, offshore Norway covering an area of ca. 15,000 km 2 . The slightly north-westwards dipping Middle Jurassic Garn Formation (Fm.) is considered as a good candidate for CO 2 storage. It is widely deposited at the Trøndelag Platform, with a thickness around 120 m and shallow buried (<2 km). It is overlain by a thick shalemudstone sequence (the Middle Jurassic Viking Group), and thick Cretaceous shales favouring a low risk for caprock leakage.Two simulation approaches were tested. First, injection in the Garn Fm. over the whole study area were simulated, to get the maximum total trap storage capacity. The modelling showed a storage capacity of 2.0 Gt with no faults and 5.2 Gt using interpreted faults at top Garn Fm. level as input to the simulations. Secondly, simulations were carried out with 38 CO 2 injection sites. From these, the injection sites which caused migration out of the study area (e.g. upward to the rim of the storage unit, with only Quaternary coverage), where removed. Finally, 7 sites with very low probability for migration out of the area were selected. These "safe" injection sites were mainly mapped in the centre of the Trøndelag Platform where only a few faults are mapped.

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Feasibility of Reproduction of Stored CO2 from the Utsira Formation at the Sleipner Gas Field

Cited by 25 publications

References 11 publications

Use of low- and high-IFT fluid systems in experimental and numerical modelling of systems that mimic CO2 storage in deep saline formations

Use of low- and high-IFT fluid systems in experimental and numerical modelling of systems that mimic CO2 storage in deep saline formations

Estimation of permeability anisotropy using seismic inversion for the CO₂ geological storage site of Sleipner (North Sea)

CO2 Storage Modelling and Capacity Estimation for the Trøndelag Platform, Offshore Norway - using a Basin Modelling Approach

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Feasibility of Reproduction of Stored CO2 from the Utsira Formation at the Sleipner Gas Field

Cited by 25 publications

References 11 publications

Use of low- and high-IFT fluid systems in experimental and numerical modelling of systems that mimic CO2 storage in deep saline formations

Use of low- and high-IFT fluid systems in experimental and numerical modelling of systems that mimic CO2 storage in deep saline formations

Estimation of permeability anisotropy using seismic inversion for the CO2 geological storage site of Sleipner (North Sea)

CO2 Storage Modelling and Capacity Estimation for the Trøndelag Platform, Offshore Norway - using a Basin Modelling Approach

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Estimation of permeability anisotropy using seismic inversion for the CO₂ geological storage site of Sleipner (North Sea)