A General Method for Subsurface CO2 Storage Capacity Calculations

Meer, Lubertus van der; Egberts, P.J.P.

doi:10.4043/19309-ms

Cited by 19 publications

(10 citation statements)

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“…It has been argued that maximum allowed bottom hole injection pressure (BHIP), system compressibility and the emplacement and density of CO 2 injection wells impose limitations on CO 2 storage capacity (e.g., [10,11]) and that the actual, dynamic storage capacity has an efficiency coefficient E of no more than 1%. Recent work [12] has shown that CO 2 storage capacity in open systems, like the aquifers assessed in this study, has a time dependency and that indeed on an engineering time scale (i.e., the life time of a CO 2 storage project), the storage efficiency coefficient E is lower, and increases asymptotically in time as more projects and injection wells come on stream to efficiently utilize the entire CO 2 storage resource.…”

Section: Methodology and Resultsmentioning

confidence: 99%

Approach to Evaluating the CO2 Storage Capacity in Devonian Deep Saline Aquifers for Emissions from Oil Sands Operations in the Athabasca Area, Canada

2014

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The Province of Alberta is the largest CO 2 emitter in Canada, with annual emissions close to 250 Mt, of which about 55 Mt CO 2 originate from oil production from oil sands. Geological storage of CO 2 has been identified as the major component of the strategy for reducing greenhouse gas emissions from oil sands operations, which are located in the Athabasca area close to the shallow eastern edge of the Alberta basin. Therefore, CO 2 storage in deep Devonian saline aquifers, located westward of the oil sands operations, may constitute a solution for storing CO 2 from these operations. A regional-scale study of the potential for storing CO 2 in deep Devonian saline aquifers in an area covering ~126,000 km 2 has been undertaken with the aim of identifying suitable sites for CO 2 storage. The Devonian sedimentary succession consists of a succession of stacked sandstone and carbonate saline aquifers separated by intervening shaly and evaporitic aquitards and aquicludes. The approach taken in the study, illustrated in this paper, comprises 11 steps, including: 1) Geological mapping of 29 Devonian formations based on information from more than 34,000 wells; 2) Hydrostratigraphic delineation of the 13 deep saline aquifers identified in this succession; 3) Determination of hydraulic continuity between various aquifers, due to depositional or erosional events; 4) Determination of formation water salinity, which ranges from less than 4000 mg/L (the limit of protected groundwater in Alberta) to close to 440,000 mg/L; 5) Determination of pressures and temperatures in these aquifers, which vary, respectively, between 1 and 30 MPa and between 12 °C and 135 °C; 6) Determination of the CO 2 phase and density at the top of each aquifer, the latter varying between < 25 kg/m 3 where CO 2 is in gas phase to > 800 kg/m 3 where CO 2 is in supercritical state; 7) Determination of well-scale porosity distribution in each aquifer, which varies between 1% and 40%,, based on well logs in 8305 wells and core analyses in 5242 wells; 8) Determination of the areal distribution of CO 2 storage capacity in each aquifer, based on aquifer thickness and porosity, and CO 2 density; 10) Determination of the regions suitable for CO 2 storage in each aquifer based on legal and regulatory constraints and protection of hydrocarbon resources; 10) Determination of permeability distributions in each aquifer, which varies from < 1 mD to > 10 D, based on 214,194 core analyses in 5242 wells and 4318 drill stem tests in 3586 wells; and 11) Identification of target areas for CO 2 storage based on local storage capacity and permeability, both of which have to be high at the local scale. Eleven prospective areas in 10 deep saline aquifers, with a cumulative storage capacity of close to 4 Gt CO 2 , have been identified as a result of this process of evaluation, screening and selection.

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Section: Methodology and Resultsmentioning

confidence: 99%

Approach to Evaluating the CO2 Storage Capacity in Devonian Deep Saline Aquifers for Emissions from Oil Sands Operations in the Athabasca Area, Canada

2014

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“…From a statistical point of view, CSLF [2,7], USDOE [3][4][5] and USGS [9,21] approaches can be considered equivalent [33], with E ranging from 1.5 to 3.6 % in open systems [26]. Similarly, closed and open system approaches cannot be statistically distinguished, although in some cases, conflicting results due to the differences in the assumptions and lacking of data are obtained.…”

Section: Comparison Of Saline Aquifers Methodologiesmentioning

confidence: 99%

“…In open systems, native fluid can be laterally or vertically displaced away from the injection area making pore space available for CO 2 [2,3,10,[17][18][19][20][21][22]. In closed or semi-closed systems, the movement of fluids is restricted within the formation impermeable boundaries [8,[23][24][25] and CO 2 capacity is mainly due to the compressibility of brine and hosting rocks [8,23,26], thereby leading to an increase in the system pressure. The major parts of storage capacity algorithms include the storage efficiency factor (E), i.e.…”

Section: Introductionmentioning

confidence: 99%

Algorithms for CO2 Storage Capacity Estimation: Review and Case Study

Cantucci

Buttinelli

Procesi

et al. 2016

Geologic Carbon Sequestration

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The estimation of CO 2 storage capacity in deep geologic formations is a pre-requisite for an efficient and safe application of Carbon Capture and Storage (CCS). The evaluation of storage resources for CO 2 geological sequestration is a challenging task and has been tackled using several static algorithms and dynamic methods, on a variety of scales ranging from country to site-specific. The purpose of this study is to present an up-to-date as well as an overall review of the storage capacity algorithms for oil and gas reservoirs, coal seams, and deep saline aquifers, including some worldwide estimation examples. Moreover, a practical application at local scale was also performed for an Italian deep reservoir located in the Po Plain (Northern Italy). The effective storage capacities were obtained applying the commonly established static methods, using both the theoretical and the geocellular volume of the reservoir. Although a conservative approach, this study demonstrates that the selected structure has favorable characteristics for CO 2 geological storage and has the capacity to host the most part of the Po Plain CO 2 emissions for several decades.

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“…On the contrary, the parameters in a dynamic model are time dependent. The most commonly used static methods are the volumetric method (Chadwick et al, 2006;DOE, 2006;Holloway, 1996), and the compressibility method (van der Meer and Egberts, 2008;Zhou et al, 2008). Examples of dynamic methods are decline curve analysis (Frailey, 2009), material balance (Mathias et al, 2009a;Zhou et al, 2008), and reservoir simulation.…”

Section: Introductionmentioning

confidence: 99%

Static and Dynamic Estimates of CO2 Storage Capacity in Two Saline Formations in the UK

Jun¹,

Pickup²,

Mackay³

et al. 2010

Proceedings of SPE EUROPEC/EAGE Annual Conference and Exhibition

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Estimation of CO 2 storage capacity is a key step in the appraisal of CO 2 storage sites. Different calculation methods may lead to widely diverging values. The compressibility method is a commonly used static method for estimating storage capacity of saline aquifers: it is simple, easy to use and requires a minimum of input data. Alternatively, a numerical reservoir simulation provides a dynamic method which includes Darcy flow calculations. More input data are required for dynamic simulation, and it is more computationally intensive, but it takes into account migration pathways and dissolution effects, so is generally more accurate and more useful. For example, the CO 2 migration plume may be used to identify appropriate monitoring techniques, and the analysis of trapping mechanism for a certain site will help to optimize well location and injection plan.Two hypothetical saline aquifer storage sites in the UK, one in Lincolnshire and the other in the Firth of Forth, were analysed. The Lincolnshire site has a comparatively simple geology, while the Forth site has a more complex geology. For each site both static and dynamic capacity calculations were performed. In the static method, CO 2 was injected till the average pressure reached a critical value. In the migration monitoring case, CO 2 was injected for 15 years was followed by a closure period lasting thousands of years. The fraction of dissolved CO 2 and the fraction immobilised by pore scale trapping were calculated.The results of both geological systems show that the migration of CO 2 is strongly influenced by the local heterogeneity. The calculated storage efficiency for the Lincolnshire site varied between 0.34% and 0.61% of the total pore volume, depending on whether the system boundaries were considered open or closed. Simulation of the deeper, more complex Forth geological system gave storage capacities as high as 1.05%.This work was part of the CASSEM (CO 2 Aquifer Storage Site Evaluation and Monitoring) integrated study to derive methodologies for assessment of CO 2 storage in saline formations. Although, static estimates are useful for initial assessment when less data is available, we demonstrate the value of performing dynamic storage calculations, and the opportunities to identify mechanisms for optimising the storage capacity.

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A General Method for Subsurface CO2 Storage Capacity Calculations

Cited by 19 publications

References 0 publications

Approach to Evaluating the CO2 Storage Capacity in Devonian Deep Saline Aquifers for Emissions from Oil Sands Operations in the Athabasca Area, Canada

Approach to Evaluating the CO2 Storage Capacity in Devonian Deep Saline Aquifers for Emissions from Oil Sands Operations in the Athabasca Area, Canada

Algorithms for CO2 Storage Capacity Estimation: Review and Case Study

Static and Dynamic Estimates of CO2 Storage Capacity in Two Saline Formations in the UK

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