Catherine Spurin

All Publications

• Dynamic Mode Decomposition of 4D imaging data to explore intermittent fluid connectivity in subsurface flows ADVANCES IN WATER RESOURCES Raizada, A., Berg, S., Benson, S. M., Tchelepi, H. A., Spurin, C. 2025; 203

  View details for DOI 10.1016/j.advwatres.2025.105013

  View details for Web of Science ID 001510737800001

• Time-resolved 2D and 3D imaging of hydrogen and brine displacement processes in porous Clashach sandstone. Journal of colloid and interface science Thaysen, E. M., Butler, I. B., Hassanpouryouzband, A., Spurin, C., Freitas, D., Rizzo, R., Alvarez-Borges, F., Atwood, R., Edlmann, K. 2025; 694: 137704

  Abstract

  Hydrogen (H2) storage in porous geological formations offers a promising means to balance supply and demand in the renewable energy sector, supporting the energy transition. Important unknowns to this technology include the H2 fluid flow dynamics through the porous medium which affect H2 injectivity and recovery. We used time-resolved X-ray computed microtomography to image real-time unsteady and steady state injections of H2 and brine (2 M KI) into a Clashach sandstone core at 5 MPa and ambient temperature. In steady state injections, H2 entered the brine-saturated rock within seconds, dispersing over several discrete pores. Over time, some H2 ganglia connected, disconnected and then reconnected from each other (intermittent flow), indicating that the current presumption of a constant connected flow pathway during multiphase fluid flow is an oversimplification. Pressure oscillations at the sample outlet were characterized as red noise, supporting observations of intermittent pore-filling. At higher H2 fractional flow the H2 saturation in the pore space increased from 20-22 % to 28 %. Average Euler characteristics were generally positive over time at all H2 flow fractions, indicating poorly connected H2 clusters and little control of connectivity on the H2 saturation. In unsteady state injections, H2 displaced brine in sudden pore-filling events termed Haines jumps, which are key to understanding fluid dynamics in porous media. Our results suggest a lower H2 storage capacity in sandstone aquifers with higher injection-induced hydrodynamic flow and suggest a low H2 recovery. For more accurate predictions of H2 storage potential and recovery, geological models should incorporate energy-dissipating processes such as Haines jumps.

  View details for DOI 10.1016/j.jcis.2025.137704

  View details for PubMedID 40318288

• The role of injection method on residual trapping: Insights into bridging scales and heterogeneity ADVANCES IN WATER RESOURCES Spurin, C., Ellman, S., Bultreys, T., Kurotori, T., Benson, S., Tchelepi, H. A. 2025; 197

  View details for DOI 10.1016/j.advwatres.2025.104913

  View details for Web of Science ID 001427851100001

• Python Workflow for Segmenting Multiphase Flow in Porous Rocks TRANSPORT IN POROUS MEDIA Spurin, C., Ellman, S., Sherburn, D., Bultreys, T., Tchelepi, H. A. 2024

  View details for DOI 10.1007/s11242-024-02136-2

  View details for Web of Science ID 001346631200001

• A Statistical Analysis of Fluid Interface Fluctuations: Exploring the Role of Viscosity Ratio. Entropy (Basel, Switzerland) Heijkoop, S., Rieder, D., Moura, M., Rucker, M., Spurin, C. 2024; 26 (9)

  Abstract

  Understanding multiphase flow through porous media is integral to geologic carbon storage or hydrogen storage. The current modelling framework assumes each fluid present in the subsurface flows in its own continuously connected pathway. The restriction in flow caused by the presence of another fluid is modelled using relative permeability functions. However, dynamic fluid interfaces have been observed in experimental data, and these are not accounted for in relative permeability functions. In this work, we explore the occurrence of fluid fluctuations in the context of sizes, locations, and frequencies by altering the viscosity ratio for two-phase flow. We see that the fluctuations alter the connectivity of the fluid phases, which, in turn, influences the relative permeability of the fluid phases present.

  View details for DOI 10.3390/e26090774

  View details for PubMedID 39330107

• The role of injection method on residual trapping at the pore-scale in continuum-scale samples INTERNATIONAL JOURNAL OF GREENHOUSE GAS CONTROL Spurin, C., Ellman, S., Bultreys, T., Tchelepi, H. A. 2024; 131

  View details for DOI 10.1016/j.ijggc.2023.104035

  View details for Web of Science ID 001147306900001

• Pore-Scale Fluid Dynamics Resolved in Pressure Fluctuations at the Darcy Scale GEOPHYSICAL RESEARCH LETTERS Spurin, C., Roberts, G. G., O'Malley, C. P. B., Kurotori, T., Krevor, S., Blunt, M. J., Tchelepi, H. 2023; 50 (18)

  View details for DOI 10.1029/2023GL104473

  View details for Web of Science ID 001066651600001

• The FluidFlower Validation Benchmark Study for the Storage of CO2 TRANSPORT IN POROUS MEDIA Flemisch, B., Nordbotten, J. M., Ferno, M., Juanes, R., Both, J. W., Class, H., Delshad, M., Doster, F., Ennis-King, J., Franc, J., Geiger, S., Glaeser, D., Green, C., Gunning, J., Hajibeygi, H., Jackson, S. J., Jammoul, M., Karra, S., Li, J., Matthaei, S. K., Miller, T., Shao, Q., Spurin, C., Stauffer, P., Tchelepi, H., Tian, X., Viswanathan, H., Voskov, D., Wang, Y., Wapperom, M., Wheeler, M. F., Wilkins, A., Youssef, A. A., Zhang, Z. 2023

  View details for DOI 10.1007/s11242-023-01977-7

  View details for Web of Science ID 001051223900002

• Pore-Scale Imaging of Multiphase Flow Fluctuations in Continuum-Scale Samples WATER RESOURCES RESEARCH Wang, S., Spurin, C., Bultreys, T. 2023; 59 (6)

  View details for DOI 10.1029/2023WR034720

  View details for Web of Science ID 001012098900001

• Dynamic mode decomposition for analysing multi-phase flow in porous media ADVANCES IN WATER RESOURCES Spurin, C., Armstrong, R. T., McClure, J., Berg, S. 2023; 175

  View details for DOI 10.1016/j.advwatres.2023.104423

  View details for Web of Science ID 001026035200001

• Red Noise in Steady-State Multiphase Flow in Porous Media WATER RESOURCES RESEARCH Spurin, C., Rucker, M., Moura, M., Bultreys, T., Garfi, G., Berg, S., Blunt, M. J., Krevor, S. 2022; 58 (7)

  View details for DOI 10.1029/2022WR031947

  View details for Web of Science ID 000825342800001

• Determination of the spatial distribution of wetting in the pore networks of rocks. Journal of colloid and interface science Garfi, G., John, C. M., Rucker, M., Lin, Q., Spurin, C., Berg, S., Krevor, S. 1800; 613: 786-795

  Abstract

  HYPOTHESIS: The macroscopic movement of subsurface fluids involved in CO2 storage, groundwater, and petroleum engineering applications is controlled by interfacial forces in the pores of rocks. Recent advances in modelling these systems has arisen from approaches simulating flow through a digital representation of the complex pore structure. However, further progress is limited by difficulties in characterising the spatial distribution of the wetting state within the pore structure. In this work, we show how observations of the fluid coverage of mineral surfaces within the pores of rocks can be used as the basis for a quantitative 3D characterisation of heterogeneous wetting states throughout rock pore structures.EXPERIMENTS: We demonstrate the approach with water-oil fluid pairs on rocks with distinct lithologies (sandstone and carbonate) and wetting states (hydrophilic, intermediate wetting, and heterogeneously wetting).FINDINGS: Fluid surface coverage the within rock pores is a robust signal of the wetting state across varying rock types and wetting states. The wetting state can be quantified and the resulting 3D maps can be used as a deterministic input to pore scale models. These may be applied to multiphase flow problems in porous media ranging from soil science to fuel cells.

  View details for DOI 10.1016/j.jcis.2021.12.183

  View details for PubMedID 35074705