Impact of Reservoir Permeability, Permeability Anisotropy and Designed Injection Rate on CO2 Gas Behavior in the Shallow Saline Aquifer at the CaMI Field Research Station, Brooks, Alberta

Yu, Xinran; Ahmadinia, Masoud; Shariatipour, Seyed M.; Lawton, Don C.; Osadetz, Kirk G.; Saeedfar, Amin

doi:10.1007/s11053-019-09604-3

Cited by 11 publications

(3 citation statements)

References 45 publications

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“…As can be seen, the permeability anisotropy ( ) of sand has no effects on the vertical migration of CO plume ( and CM / H ), which is yet highly controlled by the correlation length ( ) and density ( NTG ) of capillary barriers. Although buoyancy-driven migration of CO in homogeneous reservoir models has been shown to be highly influenced by the permeability anisotropy in previous studies 39 , our results delineate that the lateral extension and density of capillary barriers have more influential impact on retarding the upward migration of CO . According to the tornado chart, it was observed that has minimal impacts on the configuration of CO plume (i.e., , , and CM / H ) and pressure buidlup (i.e., , and ).…”

Section: Resultscontrasting

confidence: 42%

Assessing the potential of composite confining systems for secure and long-term CO2 retention in geosequestration

Bakhshian,

Bump,

Pandey

et al. 2023

Sci Rep

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A potential geologic target for CO2 storage should ensure secure containment of injected CO2. Traditionally, this objective has been achieved by targeting reservoirs with overlying seals-regionally extensive, low permeability units that have been proven capable of retaining buoyant fluid accumulations over geologic time. However, considering that the amount of CO2 is limited by a decadal injection period, vertical migration of CO2 can be effectively halted by a composite system of discontinuous shale/silt/mudstone barriers in bedded sedimentary rocks. Here, we studied the impact of depositional architectures in a composite confining system on CO2 migration and confinement at reservoir scale. We stochastically generated lithologically heterogeneous reservoir models containing discontinuous barriers consistent with statistical distributions of net-sand-to-gross-shale ratio (NTG) and horizontal correlation lengths derived from well log data and observations of producing hydrocarbon fields in Southern Louisiana. We then performed an extensive suite of reservoir simulations of CO2 injection and post-injection to evaluate the sensitivity of CO2 plume migration and pressure response of the composite system to a series of geologic and fluid parameters including the lateral continuity of barriers, NTG, permeability anisotropy within the sand body, and capillary pressure contrast between the sand and shale facies. The results indicate that lateral continuity of barriers and NTG are the dominant controls on CO2 plume geometry and pressure build-up in the reservoir, while the impact of NTG is particularly pronounced. The significance of intraformational barriers becomes apparent as they facilitate the local capillary trapping of CO2. Those barriers improve the pore space occupancy by promoting a more dispersed shape of the plume and ultimately retard the buoyancy-driven upward migration of the plume post injection.

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Section: Resultscontrasting

confidence: 42%

Assessing the potential of composite confining systems for secure and long-term CO2 retention in geosequestration

Bakhshian,

Bump,

Pandey

et al. 2023

Sci Rep

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show abstract

“…According to statistics, large-scale site projects will enter the explosive period after 2020 [3]. Most of the current research on the geological storage of CO 2 in deep saline aquifers focuses on the exploration of CO 2 migration law, storage mechanisms, and risk assessment of leakage [10][11][12][13][14]. e monitoring data from the site project show that the salt precipitation near the well is part of the low permeability zone, which causes the accumulation of injection pressure and reduces the CO 2 injectivity [15].…”

Section: Introductionmentioning

confidence: 99%

Sensitivity Analysis Strategy to Assess the Salting-Out Problem during CO2 Geological Storage Process

Ren

Feng

2021

Shock and Vibration

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The sensitivity analysis of the salting-out effect on well injectivity is a significant work in the research of geological storage of CO2 in deep saline aquifers, which is helpful in the selection of storage sites and the design of the injection strategy. We conduct a detailed sensitivity analysis about the salting-out process using the local sensitivity method and two global sensitivity methods. Sensitivity coefficients showed that brine salinity (XNaCl) has the highest sensitivity and interaction effect, the CO2 injection rate (QCO2) has a greater influence in the early stage of the salting-out process and a smaller influence in the end stage, and the other three parameters (empirical parameters related to the pore distribution m, the liquid residual saturation in the relative permeability function Splr, and the liquid residual saturation in the capillary pressure function Sclr) have a smaller sensitivity. This paper also analyzes the calculation amount of different sensitivity methods and suitable ways of obtaining the sensitivity coefficient and reveals the following. (1) The sensitivity coefficient changes dynamically with time, if only the sensitivity of the final state is taken into account on a long-time physical process, and some sensitive parameters during the process may be neglected. (2) The selection of the sample size should be based on the convergence of multiple calculations, and the results of the empirical calculation are uncertain. (3) The calculation of Sobol sensitivity is complicated, the results calculated by surrogate model depend on whether the sample is representative enough; on the other hand, it is feasible to use Sti-Si approximation to characterize the second-order sensitivity to reduce the computation. The research results not only reveal the sensitivity of the parameters related to the injection well salting-out problem during CO2 storage in deep saline aquifers but also guide the calculation of global sensitivity analysis with a similar physical process.

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“…Moreover, the fluid composition within and above the storage formation needs to be determined where the characterisation of noble gas distributions (He, Ne, Ar, Kr, Xe) may be an additional asset. 71 Besides the large scale commercial scale, various monitoring methods have also been used for smaller CO 2 pilot injection studies around the world, such as the CaMI Field Research Station project in Alberta (Canada), 72 the Otway project in Victoria (Australia), [73][74][75] the German Ketzin project, 76 the Frio Brine Pilot project in Texas (USA) 77 and in the K-COSEM storage site (South Korea). 78 After the injection phase ceases, a portion of CO 2 will be securely stored as a result of various processes including dissolution, residual and mineral trapping.…”

mentioning

confidence: 99%

A study on the impact of storage boundary and caprock morphology on carbon sequestration in saline aquifers

Ahmadinia

Shariatipour

2020

Greenhouse Gases

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Structural trapping is known to be the primary storage mechanism in geological carbon sequestration (GCS), where the injected CO 2 rises upwards due to buoyancy forces and becomes trapped under an ultra-low permeability layer. Although it is relatively common in GCS studies to assume a planar caprock for the synthesised models, in a real scenario this is not always the case as the caprock might exhibit some small-or large-scale topography changes. Moreover, little is known about the impact of the caprock morphology on the CO 2 plume migration and the storage capacity. In this work, we performed a preliminary study of the effects of boundary conditions on the CO 2 plume migration and dissolution. This was performed because most of the case study models which are employed for GCS studies are part of larger reservoirs. The obtained results were used in the simulation models of the second part of the work, to model an infinite-acting reservoir appropriately. Three different volume modifier values of 10 5 , 10 7 and 10 9 were considered on either one side or both sides of the reservoir for both horizontal and tilted caprock models. The CO 2 dissolution in the tilted models was seen to be higher once the multiplier was on the opposite side of the slope. Horizontal models closed on one side (closed faults, salt walls, etc.) were also found to exhibit more significant dissolution than models which were open from both sides. We subsequently investigated the impact of caprock morphology on the CO 2 plume advancement and its structural and dissolution trapping mechanisms by performing numerical simulations on nine synthetic models. The dissolution and migration distance are seen to be at a maximum for tilted reservoirs, where the CO 2 has more space to migrate upwards and to interact with more formation water. The lowest dissolution occurred where the significant portion of the injected CO 2 was trapped in a sand ridge or an anticline. Moreover, the possibility and also the amount of structural trapping was evaluated using an analytical method, and the results showed a fair match with the ones from the numerical simulation. We believe that this methodology could be applied for site screening prior to performing numerical simulations.

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Impact of Reservoir Permeability, Permeability Anisotropy and Designed Injection Rate on CO2 Gas Behavior in the Shallow Saline Aquifer at the CaMI Field Research Station, Brooks, Alberta

Abstract: This document is the author's post-print version, incorporating any revisions agreed during the peer-review process. Some differences between the published version and this version may remain and you are advised to consult the published version if you wish to cite from it.

Cited by 11 publications

References 45 publications

Assessing the potential of composite confining systems for secure and long-term CO2 retention in geosequestration

Assessing the potential of composite confining systems for secure and long-term CO2 retention in geosequestration

Sensitivity Analysis Strategy to Assess the Salting-Out Problem during CO2 Geological Storage Process

A study on the impact of storage boundary and caprock morphology on carbon sequestration in saline aquifers

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