Monitoring geological storage of CO2: a new approach

Fawad, Manzar; Mondol, Nazmul Haque

doi:10.1038/s41598-021-85346-8

Cited by 52 publications

(21 citation statements)

References 15 publications

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“…1 . Using this procedure in frontier areas to predict hydrocarbon may be complemented by our proposed method that combines seismic with Controlled Source Electro-Magnetic (CSEM) 39 .…”

Section: Resultsmentioning

confidence: 99%

“…Similar to our previous study 39 , we used the synthetic elastic property data from the Norwegian Geotechnical Institute (NGI). NGI generated Vp, Bulk Density, and Resistivity 40 properties using grids from a reservoir model by the Northern Light project 41 (Fig.…”

Section: Introductionmentioning

confidence: 99%

“…2 d).

Figure 2 ( a ) The original Northern Light project 41 simulation modelling grid, ( b ) location of the modelled grid area (light blue) in the northern North Sea, maps modified from the Norwegian Petroleum Directorate (NPD) data 43 , c) example of a property grid carved out to a seismic formatted cube covering only the injection and storage area, ( d ) AI and Vp/Vs ratio profiles along crossline 125 shown in ( c ), the example here is of the year 2050, the effect of injected CO 2 on both AI and Vp/Vs ratio is very subtle (Figure modified after 39 ).

Figure 3 A generalized Jurassic to Quaternary stratigraphic succession in the study area (modified from 38 , 44 ).…”

Section: Introductionmentioning

confidence: 99%

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Monitoring geological storage of CO2 using a new rock physics model

Fawad

Mondol

2022

Sci Rep

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To mitigate the global warming crisis, one of the effective ways is to capture CO2 at an emitting source and inject it underground in saline aquifers, depleted oil and gas reservoirs, or in coal beds. This process is known as carbon capture and storage (CCS). With CCS, CO2 is considered a waste product that has to be disposed of properly, like sewage and other pollutants. While and after CO2 injection, monitoring of the CO2 storage site is necessary to observe CO2 plume movement and detect potential leakage. For CO2 monitoring, various physical property changes are employed to delineate the plume area and migration pathways with their pros and cons. We introduce a new rock physics model to facilitate the time-lapse estimation of CO2 saturation and possible pressure changes within a CO2 storage reservoir based on physical properties obtained from the prestack seismic inversion. We demonstrate that the CO2 plume delineation, saturation, and pressure changes estimations are possible using a combination of Acoustic Impedance (AI) and P- to S-wave velocity ratio (Vp/Vs) inverted from time-lapse or four-dimensional (4D) seismic. We assumed a scenario over a period of 40 years comprising an initial 25 year injection period. Our results show that monitoring the CO2 plume in terms of extent and saturation can be carried out using our rock physics-derived method. The suggested method, without going into the elastic moduli level, handles the elastic property cubes, which are commonly obtained from the prestack seismic inversion. Pressure changes quantification is also possible within un-cemented sands; however, the stress/cementation coefficient in our proposed model needs further study to relate that with effective stress in various types of sandstones. The three-dimensional (3D) seismic usually covers the area from the reservoir's base to the surface making it possible to detect the CO2 plume's lateral and vertical migration. However, the comparatively low resolution of seismic, the inversion uncertainties, lateral mineral, and shale property variations are some limitations, which warrant consideration. This method can also be applied for the exploration and monitoring of hydrocarbon production.

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“…1 . Using this procedure in frontier areas to predict hydrocarbon may be complemented by our proposed method that combines seismic with Controlled Source Electro-Magnetic (CSEM) 39 .…”

Section: Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

“…2 d).

Figure 3 A generalized Jurassic to Quaternary stratigraphic succession in the study area (modified from 38 , 44 ).…”

Section: Introductionmentioning

confidence: 99%

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Monitoring geological storage of CO2 using a new rock physics model

Fawad

Mondol

2022

Sci Rep

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“…The inset in (b) does also show how the brine saturated sandstone will plot as the (1) shale content increase, (2) the amount of cement increase, (3) the porosity in the sandstone increase, (4) the effective stress in the formation decrease and (5) the saturation of gas increase within the sandstone 18 . Similar to our previous study 39 , we used the synthetic elastic property data from the Norwegian Geotechnical Institute (NGI). NGI generated Vp, Bulk Density, and Resistivity 40 properties using grids from a reservoir model by the Northern Light project 41 (Fig.…”

mentioning

confidence: 99%

“…2d). 39 ). We assumed a monitoring scenario over 40 years, with injection starting in 2020 for 25 years, keeping an assumption that the time-lapsed seismic surveys were acquired every 10 years.…”

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confidence: 99%

Monitoring Geological Storage of CO2 – A New Rock Physics Model to Estimate Saturation

Fawad¹,

Mondol²

2021

Preprint

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To mitigate the global warming crisis, one of the effective ways is to capture CO2 at an emitting source and inject it underground in saline aquifers, depleted oil and gas reservoirs, or in coal beds. This process is known as carbon capture and storage (CCS). With CCS, CO2 is considered a waste product that has to be disposed of properly, like sewage and other pollutants. While and after CO2 injection, monitoring of the CO2 storage site is necessary to observe CO2 plume movement and detect potential leakage. For CO2 monitoring, various physical property changes are employed to delineate the plume area and migration pathways with their pros and cons. We introduce a new rock physics model to facilitate the time-lapse estimation of CO2 saturation and possible pressure changes within a CO2 storage reservoir based on physical properties obtained from the prestack seismic inversion. We demonstrate that the CO2 plume delineation, saturation, and pressure changes estimation are possible using a combination of Acoustic Impedance (AI) and P- to S-wave velocity ratio (Vp/Vs) inverted from time-lapse or four-dimensional (4D) seismic. We assumed a scenario over a period of 40 years comprising an initial 25 year injection period. Our results show that monitoring the CO2 plume in terms of extent and saturation can be carried out using our rock physics-derived method. The suggested method without going into the elastic moduli level handles the elastic property cubes which are commonly obtained from the prestack seismic inversion. Pressure changes quantification is also possible within un-cemented sands; however, the stress/cementation coefficient in our proposed model needs further study to relate that with effective stress in various types of sandstones. The three-dimensional (3D) seismic usually covers the area from the reservoir's base to the surface makes it possible to detect the CO2 plume's lateral and vertical migration. However, the comparatively low resolution of seismic, the inversion uncertainties, lateral mineral, and shale property variations are some limitations, which warrant consideration. This method can also be applied for the exploration and monitoring of hydrocarbon production.

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