Ranking and Risking Alternative CO2 Storage Sites Offshore Norway

Ringrose, P.; Thorsen, R.; Zweigel, Peter; Nazarian, Bamshad; Furre, Anne-Kari; Paasch, B.; Thompson, Noel; Karstad, P.I.

doi:10.3997/2214-4609.201702142

Cited by 11 publications

(7 citation statements)

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“…The Draupne Formation comprises marine black shale, which is a rich source rock in the North Sea, and a seal for the Middle Jurassic sandstone reservoirs in the area . More importantly, it is the primary caprock for the Smeaheia − CO 2 storage site (Northern Lights), the proposed full-scale CCS project in Norway. The Draupne shale sample has a total porosity and matrix permeability in a range of 20–30% and nano- to pico-Darcy. , The MIP measurements showed a median pore diameter of 27.5 nm and a critical pore throat diameter of 9 nm. , The BET-derived specific surface area was 11 m 2 /g .…”

Section: Methodsmentioning

confidence: 99%

Effect of CO₂ Phase States and Flow Rate on Salt Precipitation in Shale Caprocks—A Microfluidic Study

Nooraiepour

Fazeli

Miri

et al. 2018

Environ. Sci. Technol.

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Fracture networks inside the caprock for CO storage reservoirs may serve as leakage pathways. Fluid flow through fractured caprocks and bypass conduits, however, can be restrained or diminished by mineral precipitations. This study investigates precipitation of salt crystals in an artificial fracture network as a function of pressure-temperature conditions and CO phase states. The impact of CO flow rate on salt precipitation was also studied. The primary research objective was to examine whether salt precipitation can block potential CO leakage pathways. In this study, we developed a novel microfluidic high-pressure high-temperature vessel to house geomaterial micromodels. A fracture network was laser-scribed on the organic-rich shales of the Draupne Formation, the primary caprock for the Smeaheia CO storage in Norway. Experimental observations demonstrated that CO phase states influence the magnitude, distribution, and precipitation patterns of salt accumulations. The CO phase states also affect the relationship between injection rate and extent of precipitated salts due to differences in solubility of water in CO and density of different CO phases. Injection of gaseous CO resulted in higher salt precipitation compared to liquid and supercritical CO. It is shown that micrometer-sized halite crystals have the potential to partially or entirely clog fracture apertures.

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Section: Methodsmentioning

confidence: 99%

Effect of CO₂ Phase States and Flow Rate on Salt Precipitation in Shale Caprocks—A Microfluidic Study

Nooraiepour

Fazeli

Miri

et al. 2018

Environ. Sci. Technol.

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“…Of these, the Sognefjord Formation at the top of the stacked aquifer offers the best properties. It occurs at approximately 1200 m depth in the Alpha prospect and has a permeability of 440-4000 mD and a porosity of 30 %-39 % (Statoil, 2016;Ringrose et al, 2017;Mondol et al, 2018). The Sognefjord Formation is capped by deep marine, organic-rich mudstones of the Draupne Formation, as well as deep water marls, carbonates and shaley units in the Cromer Knoll and Shetland groups above the base Cretaceous unconformity (Nybakken and Bäckstrøm, 1989;Isaksen and Ledjie, 2001;Kyrkjebø et al, 2004;Justwan and Dahl, 2005;Gradstein and Waters, 2016;Fig.…”

Section: Study Areamentioning

confidence: 99%

“…In order to achieve targets to reduce emissions of greenhouse gases as outlined by the European Commission (IPCC, 2014(IPCC, , 2018EC, 2018), methods of carbon capture and storage can be utilized to reach the maximum 2 • C warming goal of the Paris Agreement (e.g. Birol, 2008;Rogelj et al, 2016). One candidate for a CO 2 storage site has been identified in the Norwegian North Sea, which is the focus of this study: the saline aquifer in the Sognefjord Formation at the Smeaheia site (Halland et al, 2011;Statoil, 2016;Lothe et al, 2019).…”

Section: Introductionmentioning

confidence: 99%

Fault interpretation uncertainties using seismic data, and the effects on fault seal analysis: a case study from the Horda Platform, with implications for CO<sub>2</sub> storage

2021

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Abstract. Significant uncertainties occur through varying methodologies when interpreting faults using seismic data. These uncertainties are carried through to the interpretation of how faults may act as baffles or barriers, or increase fluid flow. How fault segments are picked when interpreting structures, i.e. which seismic line orientation, bin spacing and line spacing are specified, as well as what surface generation algorithm is used, will dictate how rugose the surface is and hence will impact any further interpretation such as fault seal or fault growth models. We can observe that an optimum spacing for fault interpretation for this case study is set at approximately 100 m, both for accuracy of analysis but also for considering time invested. It appears that any additional detail through interpretation with a line spacing of ≤ 50 m adds complexity associated with sensitivities by the individual interpreter. Further, the locations of all seismic-scale fault segmentation identified on throw–distance plots using the finest line spacing are also observed when 100 m line spacing is used. Hence, interpreting at a finer scale may not necessarily improve the subsurface model and any related analysis but in fact lead to the production of very rough surfaces, which impacts any further fault analysis. Interpreting on spacing greater than 100 m often leads to overly smoothed fault surfaces that miss details that could be crucial, both for fault seal as well as for fault growth models. Uncertainty in seismic interpretation methodology will follow through to fault seal analysis, specifically for analysis of whether in situ stresses combined with increased pressure through CO2 injection will act to reactivate the faults, leading to up-fault fluid flow. We have shown that changing picking strategies alter the interpreted stability of the fault, where picking with an increased line spacing has shown to increase the overall fault stability. Picking strategy has shown to have a minor, although potentially crucial, impact on the predicted shale gouge ratio.

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“…It occurs at approximately 1200 m depth at the Alpha prospect, and has a permeability of 440-4000 mD and a porosity of 30-39% (Statoil, 2016;Ringrose, 2017;Mondol et al, 2018). The Sognefjord Formation is capped by deep marine, organic-rich mudstones of the Draupne Formation, as well as deep water marls, carbonates and shaley units in the Cromer Knoll and Shetland Groups above the Base Cretaceous Unconformity (Nybakken and Bäckstrøm, 1989;Isaksen and Ledjie, 2001;Kyrkjebø et al, 2004;Justwan and Dahl, 2005;Gradstein and Waters, 2016; Figure 3).…”

Section: Study Areamentioning

confidence: 99%

Fault Interpretation Uncertainties using Seismic Data, and the Effects on Fault Seal Analysis: A Case Study from the Horda Platform, with Implications for CO<sub>2</sub> storage

Michie¹,

Mulrooney²,

Braathen³

2021

Preprint

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Abstract. Significant uncertainties occur through varying methodologies when interpreting faults using seismic data. These uncertainties are carried through to the interpretation of how faults may act as baffles/barriers or increase fluid flow. How fault segments are picked when interpreting structures, i.e. what seismic line spacing is specified, as well as what surface generation algorithm is used, will dictate how detailed the surface is, and hence will impact any further interpretation such as fault seal or fault growth models. We can observe that an optimum spacing for fault interpretation for this case study is set at approximately 100 m. It appears that any additional detail through interpretation with a line spacing of ≤ 50 m adds complexity associated with sensitivities by the individual interpreter. Further, the location of all fault segmentation identified on Throw-Distance plots using the finest line spacing are also observed when 100 m line spacing is used. Hence, interpreting at a finer scale may not necessarily improve the subsurface model and any related analysis, but in fact lead to the production of very rough surfaces, which impacts any further fault analysis. Interpreting on spacing greater than 100 m often leads to overly smoothed fault surfaces that miss details that could be crucial, both for fault seal as well as for fault growth models. Uncertainty in seismic interpretation methodology will follow through to fault seal analysis, specifically for analysis of whether in situ stresses combined with increased pressure through CO2 injection will act to reactivate the faults, leading to up-fault fluid flow/seep. We have shown that changing picking strategies alter the interpreted stability of the fault, where picking with an increased line spacing has shown to increase the overall fault stability. Picking strategy has shown to have minor, although potentially crucial, impact on the predicted Shale Gouge Ratio.

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Ranking and Risking Alternative CO2 Storage Sites Offshore Norway

Cited by 11 publications

References 0 publications

Effect of CO₂ Phase States and Flow Rate on Salt Precipitation in Shale Caprocks—A Microfluidic Study

Effect of CO₂ Phase States and Flow Rate on Salt Precipitation in Shale Caprocks—A Microfluidic Study

Fault interpretation uncertainties using seismic data, and the effects on fault seal analysis: a case study from the Horda Platform, with implications for CO<sub>2</sub> storage

Fault Interpretation Uncertainties using Seismic Data, and the Effects on Fault Seal Analysis: A Case Study from the Horda Platform, with Implications for CO<sub>2</sub> storage

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Ranking and Risking Alternative CO2 Storage Sites Offshore Norway

Cited by 11 publications

References 0 publications

Effect of CO2 Phase States and Flow Rate on Salt Precipitation in Shale Caprocks—A Microfluidic Study

Effect of CO2 Phase States and Flow Rate on Salt Precipitation in Shale Caprocks—A Microfluidic Study

Fault interpretation uncertainties using seismic data, and the effects on fault seal analysis: a case study from the Horda Platform, with implications for CO&lt;sub&gt;2&lt;/sub&gt; storage

Fault Interpretation Uncertainties using Seismic Data, and the Effects on Fault Seal Analysis: A Case Study from the Horda Platform, with Implications for CO&lt;sub&gt;2&lt;/sub&gt; storage

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Effect of CO₂ Phase States and Flow Rate on Salt Precipitation in Shale Caprocks—A Microfluidic Study

Effect of CO₂ Phase States and Flow Rate on Salt Precipitation in Shale Caprocks—A Microfluidic Study

Fault interpretation uncertainties using seismic data, and the effects on fault seal analysis: a case study from the Horda Platform, with implications for CO<sub>2</sub> storage

Fault Interpretation Uncertainties using Seismic Data, and the Effects on Fault Seal Analysis: A Case Study from the Horda Platform, with Implications for CO<sub>2</sub> storage