Publications
116 results found
Lin Q, Bijeljic B, Pini R, et al., 2018, Imaging and measurement of pore‐scale interfacial curvature to determine capillary pressure simultaneously with relative permeability, Water Resources Research, Vol: 54, Pages: 7046-7060, ISSN: 0043-1397
There are a number of challenges associated with the determination of relative permeability and capillary pressure. It is difficult to measure both parameters simultaneously on the same sample using conventional methods. Instead, separate measurements are made on different samples, usually with different flooding protocols. Hence, it is not certain that the pore structure and displacement processes used to determine relative permeability are the same as those when capillary pressure was measured. Moreover, at present, we do not use pore‐scale information from high‐resolution imaging to inform multiphase flow properties directly. We introduce a method using pore‐scale imaging to determine capillary pressure from local interfacial curvature. This, in combination with pressure drop measurements, allows both relative permeabilities and capillary pressure to be determined during steady state coinjection of two phases through the core. A steady state waterflood experiment was performed in a Bentheimer sandstone, where decalin and brine were simultaneously injected through the core at increasing brine fractional flows from 0 to 1. The local saturation and the curvature of the oil‐brine interface were determined. Using the Young‐Laplace law, the curvature was related to a local capillary pressure. There was a detectable gradient in both saturation and capillary pressure along the flow direction. The relative permeability was determined from the experimentally measured pressure drop and average saturation obtained by imaging. An analytical correction to the brine relative permeability could be made using the capillary pressure gradient. The results for both relative permeability and capillary pressure are consistent with previous literature measurements on larger samples.
Yao S, Pini R, Wang X, et al., 2018, Computational fluid dynamics modeling of slip flow coupled with gas adsorption/desorption kinetics in complex pore space
At reservoir conditions, gas flow confined in submicron pores of shale falls within slip flow and transition flow regimes. Beyond the common instant equilibrium assumption, we believe that gas adsorption/ desorption on rough pore surfaces could be in non-equilibrium status when gas pressure keeps decreasing during production. We investigate the interplay of gas slip flow inside complex submicron-scale pores and gas adsorption/desorption kinetics on pore surfaces with computational fluid dynamics (CFD) under unsteady-state flow conditions. Different from previous studies, the gas adsorption/desorption is in non-equilibrium state, which is closer to real reservoir conditions. Given pore pressure Pp at time t, linear driving force model with gas desorption rate coefficient kd is applied to describe the difference between the equilibrium adsorption amount (calculated with adsorption isotherms) and the actual adsorption amount per unit pore surface area. Free gas flow inside 3D reconstructions of shale pore space is modeled by Navier-Stokes equations with Maxwell's first-order slip boundary conditions. To include gas contributions from desorption, extra source with strength equal to the gas desorption rate is added to the slip boundaries. Any type of adsorption isotherms can be incorporated into our CFD modeling. We investigate the coupling of slip flow and Langmuir adsorption isotherms for methane in 3D reconstructed pore space. We observe that not all of adsorbed gas measured in adsorption isotherms contribute to gas production. In our study the pore pressure, Pp, decreases along with time t. One significant finding is that there exists a key time point, tk, after which adsorbed gas starts desorbing off pore surfaces and the decreasing rate of pore pressure becomes smaller. The higher the gas desorption rate coefficient, kd, is, the earlier tk occurs. But the decreasing rate of pore pressure is no longer sensitive to the coefficient, kd, when kd is larger than 0.0005.
Joss L, Pini R, 2017, Digital adsorption: 3D imaging of gas adsorption isotherms by X-ray computed tomography, The Journal of Physical Chemistry Part C: Nanomaterials and Interfaces, Vol: 121, Pages: 26903-26915, ISSN: 1932-7447
We report on a novel approach for the measurement of gas adsorption in microporous solids using X-ray computed tomography (CT) that we refer to as digital adsorption. Similar to conventional macroscopic methods, the proposed protocol combines observations with an inert and an adsorbing gas to produce equilibrium isotherms in terms of the truly measurable quantity in an adsorption experiment, namely the surface excess. Most significantly, X-ray CT allows probing the adsorption process in three dimensions, so as to build spatially-resolved adsorption isotherms with a resolution of approximately 10 mm3 within a fixed-bed column. Experiments have been carried out at 25 C and in the pressure range 1-30bar using CO2 on activated carbon, zeolite 13X and glass beads (as control material), and results are validated against literature data. A scaling approach was applied to analyze the whole population of measured adsorption isotherms (~7600), leading to single universal adsorption isotherm curves that are descriptive of all voxels for a given adsorbate-adsorbent system. By analyzing the adsorption heterogeneity at multiple length scales (1 mm3 to 1 cm3), packing heterogeneity was identified as the main contributor for the larger spatial variability in the adsorbed amount observed for the activated carbon rods as compared to zeolite pellets. We also show that this technique is readily applicable to a large spectrum of commercial porous solids, and that it can be further extended to weakly adsorbing materials with appropriate protocols that reduce measurement uncertainties. As such, the obtained results prove the feasibility of digital adsorption and highlight substantial opportunities for its wider use in the field of adsorptive characterization of porous solids.
Pini R, Benson SM, 2017, Capillary pressure heterogeneity and hysteresis for the supercritical CO2/water system in a sandstone, Advances in Water Resources, Vol: 108, Pages: 277-292, ISSN: 0309-1708
We report results from an experimental investigation on the hysteretic behaviour of the capillary pressure curve for the supercritical CO2-water system in a Berea Sandstone core. Previous observations have highlighted the importance of sub-core-scale capillary heterogeneity in developing local saturations during drainage; we show in this study that the same is true for the imbibition process. Spatially distributed drainage and imbibition scanning curves were obtained for mm-scale subsets of the rock sample non-invasively using X-ray CT imagery. Core- and sub-core scale measurements are well described using the Brooks-Corey formalism, which uses a linear trapping model to compute mobile saturations during imbibition. Capillary scaling yields two separate universal drainage and imbibition curves that are representative of the full sub-core scale data set. This enables accurate parameterisation of rock properties at the sub-core scale in terms of capillary scaling factors and permeability, which in turn serve as effective indicators of heterogeneity at the same scale even when hysteresis is a factor. As such, the proposed core-analysis workflow is quite general and provides the required information to populate numerical models that can be used to extend core-flooding experiments to conditions prevalent in the subsurface, which would be otherwise not attainable in the laboratory.
Liyanage R, Crawshaw, Krevor, et al., 2017, Multidimensional Imaging of Density Driven Convection in a Porous Medium, 13th International Conference on Greenhouse Gas Control Technologies, GHGT-13, Publisher: Elsevier, Pages: 4981-4985, ISSN: 1876-6102
Carbon dioxide (CO2) sequestration is a climate change mitigation technique which relies on residual and solubility trapping in injection locations with saline aquifers. The dissolution of CO2 into resident brines results in density-driven convection which further enhances the geological trapping potential. We report on the use of an analogue fluid pair to investigate density-driven convection in 3D in an unconsolidated bead pack. X-ray computed tomography (CT) is used to image density-driven convection in the opaque porous medium non-invasively. Two studies have been conducted that differ by the Rayleigh number (Ra) of the system, which in this study is changed by altering the maximum density difference of the fluid pair. We observe the same general mixing pattern in both studies. Initially, many high density fingers move downward through the bead pack and as time progresses these coalesce and form larger dominate flow paths. However, we also observe that a higher Rayleigh number leads to the denser plume moving faster towards the bottom of the system. Due to the finite size of the system, this in turn leads to early convective shut-down.
Trevisan L, Gonzalez-Nicolas A, Cihan A, et al., 2017, Experimental and modeling study of capillary/buoyancy-driven flow of surrogate CO2 through intermediate-scale sand tanks, 13th International Conference on Greenhouse Gas Control Technologies (GHGT), Publisher: ELSEVIER SCIENCE BV, Pages: 5032-5037, ISSN: 1876-6102
Trevisan L, Pini R, Cihan A, et al., 2017, Imaging and quantification of spreading and trapping of carbon dioxide in saline aquifers using meter-scale laboratory experiments, Water Resources Research, Vol: 53, Pages: 485-502, ISSN: 1944-7973
The role of capillary forces during buoyant migration of CO2 is critical towards plume immobilization within the post-injection phase of a geological carbon sequestration operation. However, the inherent heterogeneity of the subsurface makes it very challenging to evaluate the effects of capillary forces on the storage capacity of these formations and to assess in-situ plume evolution. To overcome the lack of accurate and continuous observations at the field scale and to mimic vertical migration and entrapment of realistic CO2 plumes in the presence of a background hydraulic gradient, we conducted two unique long-term experiments in a 2.44 m × 0.5 m tank. X-ray attenuation allowed measuring the evolution of a CO2-surrogate fluid saturation, thus providing direct insight into capillarity- and buoyancy-dominated flow processes occurring under successive drainage and imbibition conditions. The comparison of saturation distributions between two experimental campaigns suggests that layered-type heterogeneity plays an important role on non-wetting phase (NWP) migration and trapping, because it leads to (i) longer displacement times (3.6 months vs. 24 days) to reach stable trapping conditions, (ii) limited vertical migration of the plume (with center of mass at 39% vs. 55% of aquifer thickness), and (iii) immobilization of a larger fraction of injected NWP mass (67.2% vs. 51.5% of injected volume) as compared to the homogenous scenario. While these observations confirm once more the role of geological heterogeneity in controlling buoyant flows in the subsurface, they also highlight the importance of characterizing it at scales that are below seismic resolution (1-10 m).
Pini R, Vandehey NT, Druhan J, et al., 2016, Quantifying solute spreading and mixing in reservoir rocks using 3-D PET imaging, Journal of Fluid Mechanics, Vol: 796, Pages: 558-587, ISSN: 0022-1120
We report results of an experimental investigation into the effects of small-scale (mmcm)heterogeneities on solute spreading and mixing in a Berea Sandstone core. Pulsetracertests have been carried out in the regime Pe = 6 − 40 and are supplementedby a unique combination of two imaging techniques. X-ray CT is used to quantify subcorescale heterogeneities in terms of permeability contrasts at a spatial resolution ofabout 10 mm3, while [11C]PET is applied to image the spatial and temporal evolutionof the full tracer plume non-invasively. To account for both advective spreading andlocal (Fickian) mixing as driving mechanisms for solute transport, a streamtube model isapplied that is based on the 1D Advection Dispersion Equation. We refer to our modellingapproach as semi-deterministic, because the spatial arrangement of the streamtubes andthe corresponding solute travel times are known from the measured rock’s permeabilitymap, which required only small adjustments to match the measured tracer breakthroughcurve. The model reproduces the 3D PET measurements accurately by capturing thelarger-scale tracer plume deformation as well as sub-core scale mixing, while confirmingnegligible transverse dispersion over the scale of the experiment. We suggest that theobtained longitudinal dispersivity (0.10 ± 0.02 cm) is rock- rather than sample-specific,because of the ability of the model to decouple sub-core scale permeability heterogeneityeffects from those of local dispersion. As such, the approach presented here proves to bevery valuable, if not necessary, in the context of reservoir core analyses, because rocksamples can rarely be regarded as “uniformly heterogeneous”.
Pini R, Madonna C, 2016, Moving across scales: a quantitative assessment of X-ray CT to measure the porosity of rocks, Journal of Porous Materials, Vol: 23, Pages: 325-338, ISSN: 1380-2224
We apply multidimensional X-ray CT to quantify the porosity of Berea Sandstone by using both medical- and synchrotron-based X-ray radiation, so as to produce images of the same sample with mm- and micron-resolution, respectively. Three different samples are used and the obtained tomograms are compared by considering the spatial distribution of porosity values for the range of voxel sizes 0.25-16 mm3. The agreement between the two independent techniques is assessed by means of the concordance correlation coefficient. Statistically significant correlations are found for each sample up to the maximum resolution of the medical CT scanner, i.e. for images with a voxel size of (0.5x0.5x1) mm3. The direct comparison of images obtained by medical- and synchrotron-based X-ray radiation has a dual benefit. First, it objectively informs the segmentation step required for the binarization of the high-resolution synchrotron images that is otherwise prone to operator bias; in this context, the applicability of the proposed workflow is demonstrated with two widely applied locally adaptive thresholding algorithms, namely the hysteresis and the watershed methods. Secondly, once this calibration has occurred, the coupling of the two techniques allows analyzing porosity heterogeneity across a range of length-scales that spans over more than eight orders of magnitudes. We anticipate that the ability to perform a true multi-scale experiment may represent the required point of departure for developing up-scaling approaches that capture the inherently complex heterogeneity of rocks.
Hingerl FF, Yang F, Pini R, et al., 2016, Characterization of heterogeneity in the Heletz sandstone from core to pore scale and quantification of its impact on multi-phase flow, International Journal of Greenhouse Gas Control, Vol: 48, Pages: 69-83, ISSN: 1750-5836
Huo D, Pini R, Benson SM, 2016, A calibration-free approach for measuring fracture aperture distributions using X-ray computed tomography, Geosphere, Vol: 12, Pages: 558-571
Various methods have been proposed to measure fracture aperture distributions, including X-ray computed tomography (CT) imaging, which has the advantage that it can be combined with dynamic flow experiments. In this paper, we present a calibration-free missing CT attenuation (CFMA) imaging method for measuring fracture apertures that avoids time-consuming calibration. In addition, this model does not assume a homogeneous matrix and thus provides a good estimate of fracture apertures even when rock properties are heterogeneous. The validity of the CFMA model is established by four approaches: Comparing apertures calculated with the conventional calibration- based method; evaluating model predictability at different scanner voxel sizes; comparing with calibration coefficients in the literature from a number of experiments with different rocks and X-ray scanners; and comparing aperture measurements for dry and wet scans. We analyze the systematic error and the random error introduced by rock heterogeneities and CT scanning and show that by averaging 5 replicate scans, we reduce the aperture measurement error to ~22 μm.
Pini R, 2016, On the adsorption properties of shale rocks, Pages: 22-26
The inherent complexity of shale rocks together with their relatively low adsorption capacity as compared to commercial adsorbents represent a new scientific and technical challenge in the study of adsorption at supercritical conditions. Some of these issues are discussed in this paper. The adsorption of CO2 on a sample of Eagle Ford shale has been measured at 50°C and up to 20 MPa, and a maximum adsorption capacity of 300 SCF/ton of dry (granulated) shale sample was obtained. The analysis has focused on the estimation of the density of adsorbed gas in the pores of the material, a parameter that is key to quantify the storage capacity of shale rocks. A wide range of values was obtained (0.3-0.8 g/cm3) depending on the assumed skeletal volume of the shale. Whether these variations in the adsorbed density are related to the distinct pore structure of the materials considered and/or to uncertainties associated to the experimental techniques requires more research work under different conditions. In this context, the design an experimental protocol to accurately quantify the inaccessible volume of shale would allow improving the reliability of storage capacity estimates in these rocks.
Trevisan L, Pini R, Cihan A, et al., 2015, Experimental analysis of spatial correlation effects on capillary trapping of supercritical CO2 at the intermediate laboratory scale in heterogeneous porous media, Water Resources Research, Vol: 51, Pages: 8791-8805, ISSN: 0043-1397
Several numerical studies have demonstrated that the heterogeneous nature of typical sedimentary formations can favorably dampen the accumulation of mobile CO2 phase underneath the caprock. Core flooding experiments have also shown that contrasts in capillary entry pressure can lead to buildup of nonwetting fluid phase (NWP) at interfaces between facies. Explicit representation of geological heterogeneity at the intermediate (cm-to-m) scale is a powerful approach to identify the key mechanisms that control multiphase flow dynamics in porous media. The ability to carefully control flow regime and permeability contrast at a scale that is relevant to CO2 plume dynamics in saline formations offers valuable information to understand immiscible displacement processes and provides a benchmark for mathematical models. To provide insight into the impact of capillary heterogeneity on flow dynamics and trapping efficiency of supercritical CO2 under successive drainage and imbibition conditions, we present an experimental investigation conducted in a synthetic sand reservoir. By mimicking the interplay of governing forces at reservoir conditions via application of surrogate fluids, we performed three immiscible displacement experiments to observe the entrapment of NWP in heterogeneous porous media. Capillary trapping performance is evaluated for each scenario through spatial and temporal variations of NWP saturation; for this reason we adopted X-ray attenuation to precisely measure phase saturation throughout the flow domain and apply spatial moment analysis. The sweeping performance of two different permeability fields with comparable variance but distinct spatial correlation was compared against a homogeneous base case with equivalent mean permeability by means of spatial moment analysis.
Kumar S, Prasad M, Pini R, 2015, Selective adsorptives to study pore structure and wetting behavior of self-resourcing shales
Pore structure study using gas adsorption isotherm experiments requires homogenous adsorptive-adsorbate interactions in all pores of the porous media. This assumption is valid for a variety of industrial porous substrates, such as zeolites and activated carbon, which makes the isotherm experiment an effective tool to characterize their pore-systems. However, these systems lack the compositional heterogeneity of natural rocks. For example, organic-rich shales are composed of clay minerals, organic matter, and clay-, silt-, and sand sized particles that many have separate pore-systems with significantly different adsorptive - adsorbent interactions. These differences can lead to errors in pore characterizations based on gas adsorption. However, the contrast in adsorptive-adsorbent interactions can be exploited to study pore-selective adsorption and desorption with various adsorptives. We have used water vapor as a selective adsorptive to differentiate between hydrophilic and hydrophobic pores in shales. Our approach provides a new method of separate pore space characterization in multi-mineral systems. We studied shales and siltstones from the Bakken formation by generating subcritical isotherms for the water, hexane and nitrogen vapors.
Pini R, 2014, Assessing the adsorption properties of mudrocks for CO2 sequestration, 12TH INTERNATIONAL CONFERENCE ON GREENHOUSE GAS CONTROL TECHNOLOGIES, GHGT-12, Vol: 63, Pages: 5556-5561, ISSN: 1876-6102
Pini R, 2014, Multidimensional quantitative imaging of gas adsorption in nanoporous solids, Langmuir, Vol: 30, Pages: 10984-10989, ISSN: 1520-5827
X-ray computed tomography is applied to image gas adsorption in nanoporous solids. The equations are developed to calculate rigorous measures of adsorption, such as the excess adsorbed amount, by applying a dual-scanning technique. This approach is validated by considering the CO2/13X zeolite system in a fixed-bed adsorber, and multidimensional patterns are obtained of key characteristic properties, such as bed porosity, excess adsorption, and density of the adsorbed phase. The quantification of the spatial variability of the adsorbed amount within the system represents a major novelty with regards to conventional techniques. The ability to quantify adsorption with such a level of observational detail discloses unparalleled opportunities to interrogate and revisit adsorption processes in porous media.
Pini R, 2014, Interpretation of net and excess adsorption isotherms in microporous adsorbents, Microporous and Mesoporous Materials, Vol: 187, Pages: 40-52, ISSN: 1387-1811
Adsorption data are routinely reported as net or excess amounts adsorbed; although measuring techniques are nowadays well established, the interpretation and further use of these two measures is limited by the uncertainty on the estimated internal pore volume of the material and, accordingly, the volume (or density) of the adsorbed fluid. In this study, adsorption data are presented that have been measured with CO2 on 13X zeolite in both crystal and pellet forms at 50 °C and in the pressure range 0.02–14 MPa by using a magnetic suspension balance. The adsorbents’ structural parameters have been obtained through a combination of independent measuring techniques, including low-pressure adsorption and mercury intrusion porosimetry, and a methodology is presented where both net and excess adsorption isotherms are simultaneously evaluated through a graphical method. While providing additional insights on the meaning of these two different frameworks, the application of such an integrated approach allows for a more consistent interpretation of the obtained adsorption data. It is shown that for both materials the adsorption process is entirely controlled by the filling of the micropores and that the adsorbent’s volume is overestimated when helium is used as a probing gas. The statistical adsorption isotherm model proposed by Ruthven is applied to describe the measured adsorption isotherms and provides a much better fit than the Langmuir model. For both crystals and pellets, and over the whole pressure range, CO2 adsorbs as a dense liquid with density values starting from the critical density of the fluid and reaching 27 mol/L (i.e. 15 molecules/cage) at the highest pressure of the experiment.
Trevisan L, Pini R, Cihan A, et al., 2014, Experimental investigation of supercritical CO<sub>2</sub> trapping mechanisms at the intermediate laboratory scale in well-defined heterogeneous porous media, 12TH INTERNATIONAL CONFERENCE ON GREENHOUSE GAS CONTROL TECHNOLOGIES, GHGT-12, Vol: 63, Pages: 5646-5653, ISSN: 1876-6102
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- Citations: 8
Ruprecht C, Pini R, Falta R, et al., 2014, Hysteretic trapping and relative permeability of CO2 in sandstone at reservoir conditions, International Journal of Greenhouse Gas Control, Vol: 27, Pages: 15-27, ISSN: 1750-5836
Pini R, Benson SM, 2013, Characterization and scaling of mesoscale heterogeneities in sandstones, GEOPHYSICAL RESEARCH LETTERS, Vol: 40, Pages: 3903-3908, ISSN: 0094-8276
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- Citations: 43
Benson SM, Pini R, Reynolds C, et al., 2013, Relative permeability analysis to describe multi-phase flow in CO2 storage reservoirs
Pini R, Benson SM, 2013, Simultaneous determination of capillary pressure and relative permeability curves from core-flooding experiments with various fluid pairs, WATER RESOURCES RESEARCH, Vol: 49, Pages: 3516-3530, ISSN: 0043-1397
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- Citations: 120
Pini R, Krevor S, Krause M, et al., 2013, Capillary heterogeneity in sandstone rocks during CO<sub>2</sub>/water core-flooding experiments, International Conference on Greenhouse Gas Technologies (GHGT), Publisher: ELSEVIER SCIENCE BV, Pages: 5473-5479, ISSN: 1876-6102
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- Citations: 25
Krevor S, Pini R, Benson SM, 2013, Measurement of the multiphase flow properties of the CO<sub>2</sub>/brine system for carbon sequestration, International Conference on Greenhouse Gas Technologies (GHGT), Publisher: ELSEVIER SCIENCE BV, Pages: 4499-4503, ISSN: 1876-6102
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- Citations: 5
Marx D, Joss L, Hefti M, et al., 2013, The Role of Water in Adsorption-based CO<sub>2</sub> Capture Systems, GHGT-11, Vol: 37, Pages: 107-114, ISSN: 1876-6102
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- Citations: 15
Casas N, Schell J, Pini R, et al., 2012, Fixed bed adsorption of CO<sub>2</sub>/H<sub>2</sub> mixtures on activated carbon: experiments and modeling, ADSORPTION-JOURNAL OF THE INTERNATIONAL ADSORPTION SOCIETY, Vol: 18, Pages: 143-161, ISSN: 0929-5607
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- Citations: 106
Pini R, Krevor SCM, Benson SM, 2012, Capillary pressure and heterogeneity for the CO₂/water system in sandstone rocks at reservoir conditions, Advances in Water Resources, Vol: 38, Pages: 48-59
Schell J, Casas N, Pini R, et al., 2012, Pure and binary adsorption of CO<sub>2</sub>, H<sub>2</sub>, and N<sub>2</sub> on activated carbon, ADSORPTION-JOURNAL OF THE INTERNATIONAL ADSORPTION SOCIETY, Vol: 18, Pages: 49-65, ISSN: 0929-5607
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- Citations: 86
Krevor SCM, Pini R, Zuo L, et al., 2012, Relative permeability and trapping of CO₂ and water in sandstone rocks at reservoir conditions, Water Resources Research, Vol: 48
Casas N, Schell J, Joss L, et al., 2011, Characterization of novel adsorbent materials for a CO <inf>2</inf> capture pressure swing adsorption process
Pressure swing adsorption (PSA) is regarded as a promising technology for pre-combustion CO 2 capture, due to the boundary conditions of the separation process (high feed pressure of 35 to 40 bar and high CO 2 feed concentration of about 40%). At the same time, metal organic frameworks have attracted research interest because of their exceptional adsorption properties and their flexibility in tailoring. This work aims at assessing the potential of a metal organic framework (USO-2-Ni) with respect to the performance in separating CO 2 from H 2 in a pressure swing adsorption pre-combustion process. This is done by comparing it to a base case which was designed using commercial activated carbon as adsorbent. Both experimental and theoretical aspects related to the PSA process are investigated in this study. First a sound characterization of the two adsorbents namely activated carbon (Chemviron, Germany) and MOF is done by measuring equilibrium adsorption isotherms of CO 2, H 2 and N 2 using a Magnetic Suspension Balance (Rubotherm, Germany). Additionally physical material properties such as material and bed densities as well as heat capacities were defined. Secondly kinetic parameters, such as mass and heat transfer parameters, are determined by conducting breakthrough experiments. The interpretation of the dynamic experiments is done by describing the process with a detailed one-dimensional model consisting of mass and heat balances and several constitutive equations such as adsorption isotherms, equation of state and pressure drop correlation. The model was further validated by predicting breakthrough curves in a broad temperature and pressure range and compared to the experiments. The comparison of the results of the aforementioned experiments with simulations allowed to confirm the static adsorption measurements and to determine the rapid adsorption kinetics of CO 2 on USO-2-Ni. For the design of the PSA process several aspects are important: the energy penalty has
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