No abstract available

The Petrel Sub-basin Marine Survey GA-0335 (SOL5463) was acquired by the RV Solander during May 2012 as part of the Commonwealth Government's National Low Emission Coal Initiative (NLECI). The survey was undertaken as a collaboration between the Australian Institute of Marine Science (AIMS) and GA. The purpose was to acquire geophysical and biophysical data on shallow (less then 100m water depth) seabed environments within two targeted areas in the Petrel Sub-basin to support investigation for CO2 storage potential in these areas. Underwater video footage and still photographic images (12 megapixel resolution) from towed-video were acquired from 11 stations. The quality of imagery varies among transects and some still images were not of suitable quality for analysis. No still images are available for stations 2, 4 and 7 due to system malfunction. Video and still image files and associated parent folders are named by station number, gear code (CAM = underwater camera system) and then the deployment number. For example 'STN08CAM06' would represent a video transect from Station 08 that was the 6th video transect of the survey. Please note that the Ultra-short Baseline (USBL) acoustic tracking system used to track the towed-camera system failed early in the survey; hence geo-location of video transects and stills could only be linked to the R.V. Solander's ship navigation.

The Lower Cretaceous Gage Sandstone is a deep saline aquifer which is overlain by the regionally extensive Lower Cretaceous South Perth Shale seal in the offshore Vlaming Sub-basin, Perth Basin, Australia. This paper is focused on the CO2 storage capacity estimation in the Gage reservoir by integrating both the well and seismic data. After a 3D grid system was constructed, well log interpretations, depth converted interval velocity and seismic relative acoustic impedance data were imported into the 3D grids. The volume fraction of shale was first constructed combining the neural networks modelling and residual stochastic simulation from the well and seismic attributes data. Porosity was modelled using sequential Gaussian co-simulation with the volume fraction of shale model. The CO2 storage capacity was estimated using the total pore volume and storage coefficients in US-DOE methodology. The best estimate (P50) of carbon storage capacity in the Gage Sandstone reservoir is 493 million tonnes based on the static reservoir modelling. This article was submitted to Energy Procedia November 2018. <b>Citation:</b> Liuqi Wang, Megan Lech, Chris Southby, Irina Borissova, Victor Nguyen, David Lescinsky, <i>CO2 storage capacity estimation through static reservoir modelling: A case study of the lower Cretaceous Gage Sandstone reservoir in the offshore Vlaming Sub-basin, Perth Basin, Australia, </i>Energy Procedia, Volume 154, <b>2018</b>, Pages 54-59, ISSN 1876-6102, https://doi.org/10.1016/j.egypro.2018.11.010.

There are numerous isotopic tracers that have the potential to track the movement of CO2 as it is sequestered underground. Their primary role is in verifying the presence of sequestered CO2. These tracers range from CO2 to 3He to PFT?s to SF6. With such a variety of possible tracers, it is important to identify which tracer(s) are (a) economically viable, (b) can be measured appropriately, (c) fit with the specifics of the geological site, and (d) meet the concerns of the public. Tracers can be used either in a continuous mix with the whole body of sequestered gas as an ownership label or in a pulse to monitor changes in the reservoir characteristics of the body of rock hosting the sequestered gas. Rather than going to the expense of adding a tracer to the stream of sequestered CO2 there may be the opportunity to use natural tracers, such as the very CO2 being injected. In the Weyburn Project, the CO2 injected was isotopically distinct from any CO2 that might have been present in the geological system to which it was being added. The CO2 piped from a gasification plant in North Dakota had an isotopic signature quite depleted in 13C (approx. ?13C -20 to -30?; ref Hirsche et al., 2004). This contrasted with the carbonate minerals and any CO2 present in the hydrocarbon reservoir to which the gas was being sequestered as part of an enhanced oil recovery (EOR) project. Unfortunately, the sequestered CO2 may not be as isotopically different as background sources, for example separating CO2 from natural gas prior to re-injection in the same formation. Costs of tracers per litre can range in orders of magnitude; however the cost should be measured as amount per metric tonne CO2 in order to obtain the true cost. Amounts required tend to be controlled by the background atmospheric presence of any tracer and by the sampling methods and locations. For example, the amount of tracer used to monitor subsurface movement of CO2 from an injection to a monitoring well would potentially be very low if that tracer is not present in deep saline aquifers. However, if shallow water bores or soil or atmospheric level measurements are also being taken, then the presence of the tracer in the soil or atmosphere will strongly control how much additional tracer is required to see changes above background. Addition of 14CO2 to sequestered CO2 may be regarded as a cost effective tracer that will closely mimic CO2. However, it will not advance ahead of the sequestered CO2, it will mask natural differences in 13C/14C variations in the soil and atmosphere, and of course is radiogenic and therefore less favored by the public. By contrast, SF6 (sulphur hexafluoride) is also inexpensive, and has been used in a variety of tracer experiments (Tingey et al., 2000 and references therein). However, SF6 is required in larger volumes (engineering issue for mixing), is increasing in presence in the atmosphere (Maiss and Brenninkmeijer, 1998) and is a highly potent greenhouse gas. As an example of its global warming potential (GWP), 5500 tonnes SF6 is the equivalent of releasing 132 million tons of CO2 (Maiss and Brenninkmeijer, 1998).

This dataset shows the key Australian petroleum producing basins ranked by their potential for CO2 enhanced oil recovery (CO2-EOR), based on a study completed by Geoscience Australia in 2020. Basin rankings result from the assessment of six parameters: the API gravity of the oil, temperature, pressure, reservoir quality (porosity, permeability), nearby CO2 sources and existing infrastructure. Higher rankings indicate greater potential for CO2-EOR. For further information see: Tenthorey, E., and Kalinowski, A. 2022. Screening Australia’s Basins for CO2-Enhanced Oil Recovery. Proceedings of the 16th Greenhouse Gas Control Technologies Conference (GHGT-16) 23-24 Oct 2022. Available at SSRN: https://ssrn.com/abstract=4294743 or http://dx.doi.org/10.2139/ssrn.4294743.

This web map service shows the key Australian petroleum producing basins ranked by their potential for CO2 enhanced oil recovery (CO2-EOR), based on a study completed by Geoscience Australia in 2020. Basin rankings result from the assessment of six parameters: the API gravity of the oil, temperature, pressure, reservoir quality (porosity, permeability), nearby CO2 sources and existing infrastructure. Higher rankings indicate greater potential for CO2-EOR. For further information see: Tenthorey, E., and Kalinowski, A. 2022. Screening Australia’s Basins for CO2-Enhanced Oil Recovery. Proceedings of the 16th Greenhouse Gas Control Technologies Conference (GHGT-16) 23-24 Oct 2022. Available at SSRN: https://ssrn.com/abstract=4294743 or http://dx.doi.org/10.2139/ssrn.4294743.

This web map service shows the key Australian petroleum producing basins ranked by their potential for CO2 enhanced oil recovery (CO2-EOR), based on a study completed by Geoscience Australia in 2020. Basin rankings result from the assessment of six parameters: the API gravity of the oil, temperature, pressure, reservoir quality (porosity, permeability), nearby CO2 sources and existing infrastructure. Higher rankings indicate greater potential for CO2-EOR. For further information see: Tenthorey, E., and Kalinowski, A. 2022. Screening Australia’s Basins for CO2-Enhanced Oil Recovery. Proceedings of the 16th Greenhouse Gas Control Technologies Conference (GHGT-16) 23-24 Oct 2022. Available at SSRN: https://ssrn.com/abstract=4294743 or http://dx.doi.org/10.2139/ssrn.4294743.

This web map service shows the key Australian petroleum producing basins ranked by their potential for CO2 enhanced oil recovery (CO2-EOR), based on a study completed by Geoscience Australia in 2020. Basin rankings result from the assessment of six parameters: the API gravity of the oil, temperature, pressure, reservoir quality (porosity, permeability), nearby CO2 sources and existing infrastructure. Higher rankings indicate greater potential for CO2-EOR. For further information see: Tenthorey, E., and Kalinowski, A. 2022. Screening Australia’s Basins for CO2-Enhanced Oil Recovery. Proceedings of the 16th Greenhouse Gas Control Technologies Conference (GHGT-16) 23-24 Oct 2022. Available at SSRN: https://ssrn.com/abstract=4294743 or http://dx.doi.org/10.2139/ssrn.4294743.

Residual CO2 saturation (Sgr-CO2) is considered one of the most important trapping mechanisms for geological CO2 storage. Yet, standard procedures for the determination of Sgr-CO2 are missing and Sgr-CO2 has not been determined quantitatively at reservoir until recently. This circumstance introduces uncertainty in the prediction of the nature and capacity of CO2 storage and requires the development of well test procedures. The CO2CRC drilled a dedicated well with perforations in a low salinity aquifer of the Paaratte Formation between 1440 - 1447 m below the surface of the Otway Basin, Australia, with the aim to develop and compare five methods to determine Sgr-CO2 (see also Paterson et al, this volume).

This is a 3 minute movie (with production music), to be played in the background during the October 28th 2010 Geoscience Australia Parlimentary Breakfast. The video shows a wide range of the types of activities that GA is involved in. These images include GA people doing GA activities as well as some of the results of offshore surveys; continental mapping; eath monitoring etc. The movie will be played as a background before and after GA's CEO (Chris Pigram) presentation.