Australia’s CO2 geological storage potential and matching of emission sources to potential sinks

Bradshaw, J. D.; Allinson, Guy; Bradshaw, Barry E.; Nguyen, Victor; Rigg, Andy; Spencer, L.; Wilson, P.A.

doi:10.1016/j.energy.2004.03.064

Cited by 36 publications

(13 citation statements)

References 7 publications

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“…Deep saline aquifers and coal beds can be used successfully for CO 2 sequestration if large enough capacity and a confining structure exist in a stable geological environment (Bachu ; Bachu & Adams ; Bradshaw et al . ; Bachu & Dusseault ; IPCC ). Compared to other geological formations such as mature oil and gas fields and unminable coal seams, deep saline aquifers have the highest storage capacity (1000–10 000 GtCO 2 ), and the environmental risks of using them to store CO 2 are considered to be at an acceptable medium level (Shukla et al .…”

Section: Introductionmentioning

confidence: 99%

Experimental investigation of carbon dioxide trapping due to capillary retention in saline aquifers

Akbarabadi

Karpyn

et al. 2015

Geofluids

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Capillary trapping is a physical mechanism by which carbon dioxide (CO 2 ) is naturally immobilized in the pore spaces of aquifer rocks during geologic carbon sequestration operations, and thus a key aspect of estimating geologic storage potential. Here, we studied capillary trapping of supercritical carbon dioxide (scCO 2 ), and the effect of initial scCO 2 saturation and flow rate on the storage/trapping potential of Berea sandstone. We performed two-phase, scCO 2 -brine displacements in two samples, each subject to four sequential drainage-imbibition coreflooding cycles to quantify end-point saturations of scCO 2 with the aid of micro-and macro-computed tomography imaging. From these experiments, we found that between 51% and 75% of the initial CO 2 injected can be left behind after the brine injection. We also observed that the initial scCO 2 saturation influenced the residual scCO 2 saturation to a greater extent than the rate of brine injection under the experimental conditions examined. In spite of differences in the experimental conditions tested, as well as those reported in the literature, initial and residual saturations were found to follow a consistent relationship.

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Section: Introductionmentioning

confidence: 99%

Experimental investigation of carbon dioxide trapping due to capillary retention in saline aquifers

Akbarabadi

Karpyn

et al. 2015

Geofluids

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“…Methodical evaluation of geologic CO 2 -sequestration resources at large scales dates back nearly two decades; thus, a substantial body of literature examining seques-tration potential at the national, regional, or basin level exists (van der Meer, 1992;Bergman and Winter, 1995;Bachu, 2003;Bradshaw et al, 2004;National Energy Technology Laboratory (NETL), 2006, 2008, 2010Bachu et al, 2007;Dilmore et al, 2008;Burruss et al, 2009;Dahowski et al, 2009;Frailey, 2009;Frailey and Finley, 2009;Michael et al, 2009a, b;Brennan et al, 2010;Goodman et al, 2011;Szulczewski et al, 2012). Studies on sequestration resource evaluation at a basin scale help us to understand how CCS technologies may work in theory; these studies provide a preliminary assessment of the prospective impact of CCS technology deployment on CO 2 emission reduction at the national or regional level.…”

Section: Concepts and Approachesmentioning

confidence: 99%

“…Basin-scale CO 2 storage resource assessments in one form or another have been conducted for approximately two decades (McKelvey, 1972;van der Meer, 1992;Bergman and Winter, 1995;National Energy Technology Laboratory (NETL), 2006, 2008, 2010Bradshaw et al, 2004;Dilmore et al, 2008;Bradshaw et al, 2009;Burruss et al, 2009;Michael et al, 2009a, b;Brennan et al, 2010;Goodman et al, 2011). Today, an increased emphasis on the distribution, potential volume, and cost to develop CO 2 geologic sequestration resources exists (Alley et al, 2007;van der Meer and Egberts, 2008;Dooley, 2010;Szulczewski et al, 2012).…”

Section: Introductionmentioning

confidence: 99%

Comparative analysis of carbon dioxide storage resource assessment methodologies

Popova¹,

Small²,

McCoy³

et al. 2012

Environ. Geosci.

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Today, an increased emphasis on the distribution, potential volume, and cost to develop CO 2 geologic sequestration resources exists. In the presence of climate change, the need to make accurate and clearly understandable assessments of carbon sequestration potential, which can be used by the government and industry to plan for technology deployment, has never been greater. We compare three CO 2 storage assessment methodologies: the approach applied by the U.S. Department of Energy in its Carbon Atlas III, the modified U.S. Geological Survey methodology, and the CO 2 Geological Storage Solutions methodology. All three methodologies address storage resources in porous geologic media in sedimentary basins, namely oil and gas reservoirs and saline formations. Based on our analyses, these methodologies are similar in terms of computational formulation. We find that each of the proposed methodologies is science and engineering based. As such, they are important in identifying the geographical distribution of CO 2 storage resource and regional carbon sequestration potential at the national and basin-scale levels for use in energy-related government policy and business decisions. Policy makers need these high-level estimates to evaluate the prospective function that carbon capture and sequestration technologies can play in reducing CO 2 emissions over the long term. The value of these high-level assessments of CO 2 storage resource is to help inform decision makers in governments and industry as to whether carbon capture and sequestration is a climate mitigation option worth pursuing in particular regions.

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“…al. (2003) identify 378.5 MtC of storage capacity in offshore deep saline formations capacity. Akimoto asserts that their assumptions for capacity in offshore fields is conservative and that they only assessed regions with known anticline structures and with high quality data.…”

Section: Japan: Textbox 1: Key Assumptions For Co2 Storage Capacity Imentioning

confidence: 99%

“…• Bradshaw et al (2003) identifies 720 GtCO2 as the total theoretical storage capacity for Australia. • IEAGHG (1998) identify 29.9GtCO2 storage capacity contained within the Bowen (11.2 GtCO2), Sydney (7.8 GtCO2), Clarnce/Moreton (3.4 GtCO2), Gunnedah (3.2 GtCO2), and Gailee(4.3 GtCO2) coal basins.…”

Section: Assumptions For Australia and New Zealandmentioning

confidence: 99%

A Global but Regionally Disaggregated Accounting of CO2 Storage Capacity: Data and Assumptions for Compiling Regional CO2 Storage Capacity Supply Curves for Incorporation within ObjECTS->MiniCAM

Dooley¹,

Friedman²

2005

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This technical working paper lays out the assumptions and data sources used to calculate a regionally disaggregated assessment of the carbon dioxide (CO2) storage capacity of various geologic reservoirs. We present estimates of CO2 storage capacity in the following classes of reservoirs: depleted oil plays, coal beds, depleted gas basins, deep saline formations, and offshore deep saline formations. CO2 storage capacity for each of these classes of candidate geologic reservoirs were estimated by consulting the technical literature or through our own technical judgment for the following regions of the

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Australia’s CO2 geological storage potential and matching of emission sources to potential sinks

Cited by 36 publications

References 7 publications

Experimental investigation of carbon dioxide trapping due to capillary retention in saline aquifers

Experimental investigation of carbon dioxide trapping due to capillary retention in saline aquifers

Comparative analysis of carbon dioxide storage resource assessment methodologies

A Global but Regionally Disaggregated Accounting of CO2 Storage Capacity: Data and Assumptions for Compiling Regional CO2 Storage Capacity Supply Curves for Incorporation within ObjECTS->MiniCAM

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