masoudi

• Masoudi, Mohammad; Bergmo, Per Eirik Strand & Grimstad, Alv-Arne (2026). Smart Inflow Control for Water Management: Case Studies From the Norne and Volve Oilfields. In 2026, OMAE (Eds.), Proceedings of ASME 2026 45th International Conference on Ocean, Offshore and Arctic Engineering : Volume 9 : Petroleum Technology. The American Society of Mechanical Engineers (ASME). ISSN 9780791889589. doi: 10.1115/omae2026-177037. Full text in Research Archive Show summary

  This paper investigates advanced inflow control for managing water production in mature fields, using two field-scale simulation case studies from the Norne and Volve oilfields on the Norwegian Continental Shelf. In both cases, density-activated recovery (DAR) autonomous inflow control devices were implemented in multi-segmented wells and tested under a range of water-cut (WCT) thresholds and nozzle configurations, with base cases representing conventional completions without inflow control. In the modified Norne model, moderate shutoff settings achieve 20–37% reductions in produced water and corresponding reductions in water injection, while limiting cumulative oil losses to 3–9%. More aggressive shutoff yields larger water savings but becomes increasingly penalizing for oil production and is unlikely to be optimal from an economic perspective. In the more heterogeneous and faulted Volve model, incorporating realistic valve hysteresis and moderate choking improves cumulative oil production relative to the base case, while reducing produced water by up to 85% and lowering the need for injection and water treatment. Together, the two case studies demonstrate that properly tuned autonomous inflow control can significantly reduce water handling and associated energy use, while maintaining or even enhancing oil recovery, provided that WCT limits and valve configurations are optimized to field-specific conditions.

• Hellevang, Helge; Fischer, Cornelius; Nooraiepour, Mohammad; Molins, Sergi; Masoudi, Mohammad & Prasianakis, Nikolaos I. (2026). Bridging Nanoscopic Surface Heterogeneity and Macroscopic Nucleation Rates: A Perspective on Probabilistic Approaches. Crystal Growth & Design. ISSN 1528-7483. doi: 10.1021/acs.cgd.6c00312. Full text in Research Archive Show summary

  Abstract Predicting the number of newly formed crystals and their spatial distribution on surfaces or within pore spaces matters across many fields, from structural biology to coupled fluid flow and reactive transport in porous media to atmospheric physics. Nucleation occurs at molecular and nanoscopic scales, yet classical nucleation theory (CNT) provides an averaged, macroscopic description, and a growing body of experimental observations is inconsistent with CNT predictions. Probabilistic nucleation models have been developed to predict mineral formation in reactive porous geochemical systems and to generate uncertainty estimates, for example, of how mineral growth affects fluid flow. However, the probability density functions of nucleation rates or induction times that underlie these models remain poorly constrained and are not grounded in the intrinsic nanoscopic physicochemical mechanisms underlying the observed macroscopic behavior. This perspective reviews recent advances in mineral nucleation research, focusing on modeling in coupled reactive transport systems, and examines how the large uncertainties reported for macroscopic nucleation rates may be linked to the extent and spatial distribution of surface sites with contrasting reactivity, such as kinks, steps, and terraces. Building on this, we propose a framework that integrates site-specific nucleation probabilities and explicitly accounts for polymorph selection to enable deterministic prediction of macroscopic nucleation rates from intrinsic surface properties. While the resulting parameter space is extensive, recent advances in machine learning, combined with high-throughput experimentation and simulation, suggest that such predictive, multiscale models are now within reach.

• Emmel, Benjamin; Stroisz, Anna Magdalena; Bjørkvik, Bård Johan Arnt; Jeante, Anthime; Cerasi, Pierre & Johnson, James Ronald [Show all 8 contributors for this article] (2026). Multianalytical Assessment of Shale Behavior after Medium-Pressure/Temperature Hydrogen Exposure. Energy & Fuels. ISSN 0887-0624. 40(34), p. 19134–19150. doi: 10.1021/acs.energyfuels.6c02121. Full text in Research Archive Show summary

  Underground hydrogen (H2) storage (UHS) in siliciclastic porous reservoirs relies critically on the long-term integrity of shale caprocks. However, the influence of H2 on shale microstructure, elastic properties, and mechanical strength remains poorly constrained. This study investigates H2–rock interactions in shales from the Draupne Formation (i.e., Kimmeridge equivalent), a regionally important sealing unit on the Norwegian Continental Shelf. Samples from two wells representing contrasting shale facies were exposed for 7 days to 170 ± 1 bar and 60 ± 1 °C under either H2 or inert Ar atmospheres. Pre- and postexposure characterization employed X-ray micro-CT, scanning electron microscopy coupled with energy dispersive spectroscopy (SEM-EDS), ultrasonic through-transmission acoustic wave velocity measurements, punch testing, and gas chromatography (GC). The two facies exhibit strong compositional and structural heterogeneity, with Draupne Shale 1 (DS1) dominated by carbonate-rich, relatively homogeneous layers, and DS2 characterized by organic-rich and laminated microstructures. SEM-EDS and GC analyses revealed no measurable evidence of mineralogical or chemical alteration, indicating that at these pressure and temperature (PT) conditions H2 does not react measurably with shale constituents. Acoustic velocities display small but inconsistent changes after gas exposure, which are best explained by sample heterogeneities and/or P-induced microcrack changes rather than H2-specific effects. In contrast, punch tests reveal distinct facies-dependent mechanical responses: DS2 shale shows reduced peak shear strength and more brittle postpeak behavior after H2 exposure, whereas Ar-treated samples remain more ductile. These results suggest that H2 may contribute to weakening along pre-existing heterogeneities in more compliant shale facies, even in the absence of detectable chemical reactions. The study demonstrates that microstructural variability governs shale behavior during H2 exposure and highlights the need for facies-specific assessment in UHS applications.

• Da̧browski, Karol M.; Nooraiepour, Mohammad & Masoudi, Mohammad (2026). Transport-Controlled Halite Crystallization Kinetics during Geological CO2 Storage: Pore-Scale Quantification of Coupled Phase-State, Flow-Rate, and Temperature Effects on Near-Wellbore Precipitation. Energy & Fuels. ISSN 0887-0624. 40(24), p. 12945–12958. doi: 10.1021/acs.energyfuels.6c00898. Full text in Research Archive Show summary

  Salt precipitation near injection wells can reduce permeability, drive excess pressure buildup, and impair injectivity within days to weeks of CO2 injection; yet, the pore-scale mechanisms coupling multiphase flow, evaporation, and crystallization remain poorly quantified across different phase states and flow regimes. To address this gap, we present high-resolution microfluidic experiments that systematically quantify halite crystallization dynamics during CO2-driven brine evaporation in liquid, gaseous, and supercritical phases (50–80 bar, 20–60 °C, Pe = 50–1440). Crystallization kinetics are transport-controlled: the Avrami rate constant (K) increases by 2 orders of magnitude with the Péclet number and follows Arrhenius temperature dependence (Ea = 62.6 kJ/mol). Supercritical CO2 achieves superior displacement efficiency (residual saturation 0.22–0.36; fractal dimension D = 1.79–1.82) and the fastest evaporation rates (Sherwood numbers 2–3× higher than the liquid phase), compressing crystallite formation times from 57 min at 20 °C (liquid phase) to under 1 min at 40–60 °C (gas and supercritical phases). Final crystal area fractions increase 10-fold from liquid (∼0.008) to gas-phase conditions (0.08–0.12), confirming that convective transport and phase state dominate over diffusion-limited mechanisms under our experimental conditions. Despite inherently probabilistic nucleation, final crystal distributions within the microfluidic chip are spatially deterministic, with no systematic inlet-to-outlet bias observed across all tested conditions. Together, the quantitative relationships among dimensionless parameters (Pe, Sh), kinetic constants (K, Ea), and phase-dependent displacement patterns provide critical benchmarks for validating pore-scale models and predicting near-wellbore permeability impairment during geological CO2 storage in saline and hypersaline aquifers.

• Dąbrowski, Karol M.; Nooraiepour, Mohammad; Masoudi, Mohammad; Soomro, Ahsan N.; Smulski, Rafał & Barbacki, Jan [Show all 8 contributors for this article] (2026). Pore-scale salt precipitation during CO2 injection: How additives and interfacial tension govern crystallization? International Journal of Greenhouse Gas Control. ISSN 1750-5836. 154, p. 104695–104695. doi: 10.1016/j.ijggc.2026.104695. Full text in Research Archive
• Nooraiepour, Mohammad; Masoudi, Mohammad; Derluyn, Hannelore; Senechal, Pascale; Moonen, Peter & Hellevang, Helge (2026). Halite precipitates as porous crystalline networks, not dispersed crystals: Self-enhancing growth mechanisms during CO₂ storage in saline aquifers. Chemical Engineering Journal. ISSN 1385-8947. 543, p. 1–15. doi: 10.1016/j.cej.2026.178165. Full text in Research Archive Show summary

  Salt precipitation during CO₂ injection into saline aquifers obstructs flow-controlling pore throats and reduces injectivity, yet reactive transport models assume dispersed, non-porous crystals with negligible fluid flow impact. Here, we demonstrate that halite develops three-dimensional porous networks with 40 ± 15% internal porosity through self-enhancing growth mechanisms. Time-lapse X-ray micro-computed tomography and spectral imaging reveal preferential nucleation at gas-liquid interfaces, where porous hydrophilic aggregates generate capillary suction that draws brine films toward precipitation sites, thereby accelerating growth and expanding the reactive surface area in a positive feedback loop. Spectral tomography identifies two-stage precipitation: dense macrocrystalline cores formed under moderate supersaturation and evaporation, surrounded by microcrystalline overgrowths from rapid late-stage dynamics that produce umbrella-like crusts encapsulating residual brine. This porous architecture explains why modest bulk porosity reduction causes disproportionate permeability decline, as aggregates preferentially obstruct flow percolation pathways rather than uniformly cementing grains or filling pore space. Five interconnected mechanisms drive self-enhancing growth across nano- to centimeter scales: interface nucleation, secondary porous structure formation, steep concentration gradients, hydrophilic substrate film maintenance, and capillary-driven solute delivery. Pore network quantification delivers the first three-dimensional structural characterization of halite growth architecture under GCS-relevant conditions, resolving pore diameter distributions of 20–200 μm, mean coordination numbers of 5, and reactive surface areas averaging 0.04 mm2 per pore – parameters currently absent from reactive transport models yet essential for predicting injectivity impairment and containment integrity at operational storage scales.

• Nooraiepour, Mohammad; Masoudi, Mohammad & Hellevang, Helge (2026). Carbon Mineralization in CO2–Seawater–Basalt Systems: Reactive Transport Dynamics and Vesicular Pore Architecture Controls. Langmuir. ISSN 0743-7463. 42(16), p. 11435–11456. doi: 10.1021/acs.langmuir.6c00958. Full text in Research Archive Show summary

  Carbon mineralization in basaltic rocks offers a promising pathway for rapid, permanent CO2 storage, yet fundamental controls on reactive transport, precipitation patterns, and permeability evolution under seawater conditions remain poorly constrained. This study integrates flow-through column experiments at 80 °C with CO2-acidified seawater, geochemical modeling, and multiscale pore imaging (SEM-EDS and micro-CT) to elucidate mineralization dynamics in basaltic glass. Results demonstrate that carbonate precipitation is nucleation-limited and kinetically controlled rather than thermodynamically driven or growth-dominated, forming discrete patchy accumulations despite sustained supersaturation. An order-of-magnitude reduction in flow rate (0.05 to 0.005 mL/min) was required to achieve visible precipitation, highlighting residence time as the primary control. Postexperiment characterization identified calcium carbonate and inferred smectite-like clays, with dissolution-induced surface roughening and localized precipitation evident across the column. Seawater chemistry further complicates mineralization kinetics and efficiency relative to freshwater systems. Micro-CT analysis of three vesicular basalt facies revealed low coordination numbers (modal = 2) and serial connectivity, contrasting sharply with higher-coordination sandstone networks. The connected porosity (1.3–32%) differs significantly from the total segmented porosity (18–42%), demonstrating that network topology, rather than total porosity, controls permeability. Pore-scale observations thus indicate that precipitation may render basalts inherently more vulnerable to permeability impairment from modest, distributed precipitation. We explore end-member precipitation-induced clogging scenarios in which small, distributed precipitates cause disproportionately severe permeability loss compared to large, isolated masses. These findings underscore the need for probabilistic reactive transport frameworks that incorporate realistic pore topologies and nucleation barriers, which are fundamentally different from conventional CCS in sedimentary reservoirs, to improve predictions of injectivity and long-term carbon mineralization performance in mafic formations.

• Dąbrowski, K.M.; Nooraiepour, Mohammad & Masoudi, Mohammad (2026). Microfluidic study of evaporation-driven crystallization of saline and ammonia brines under hydrogen flow. International Journal of Hydrogen Energy. ISSN 0360-3199. 219, p. 1–17. doi: 10.1016/j.ijhydene.2026.154090. Full text in Research Archive Show summary

  Underground hydrogen storage in geological formations is critical for renewable energy integration, but salt precipitation during gas injection can impair storage performance. While well studied for CO2 systems, precipitation mechanisms in hydrogen–brine and ammonia–brine systems remain poorly understood. This study presents a systematic microfluidic investigation of salt crystallization during hydrogen injection into saline and ammonia-containing brine aquifers under high pressure with varying compositions (1–5 mol/kg NaCl), chemical additives (surfactants, alcohols, ammonia), and hydrogen flow rates (200–1300 mL/min). Quantitative imaging shows hydrogen induces physical precipitation through evaporation and capillary trapping, resulting in discrete deposits, whereas CO2-ammonia systems produce interconnected ammonium bicarbonate networks. Interfacial tension controls brine distribution and crystal coverage: high-IFT fluids form large pools promoting crystallization, low-IFT fluids form isolated pools reducing coverage by 50%. Alcohols and surfactants suppress precipitation, while ammonia increases crystal fraction. Higher flow rates accelerate crystallization, highlighting gas-specific mitigation strategies for underground hydrogen storage.

• Masoudi, Mohammad; Meyra, Ariel G.; Nooraiepour, Mohammad; Nezhad, Mohaddeseh Mousavi; Hassanpouryouzband, Aliakbar & Hellevang, Helge (2026). Revisiting Hydrogen Sorption–Desorption in Natural Rocks. Industrial & Engineering Chemistry Research. ISSN 0888-5885. 65(6), p. 2984–3026. doi: 10.1021/acs.iecr.5c02081. Full text in Research Archive Show summary

  Hydrogen sorption and desorption in natural rocks are increasingly referenced across subsurface energy and environmental applications, including underground hydrogen storage, natural hydrogen exploration, geological hydrogen generation, and radioactive waste containment. However, the extent to which these physical interactions influence hydrogen behavior in geological materials remains poorly understood. This review examines current experimental and theoretical studies (atomistic simulation and isotherm modeling) of hydrogen sorption and desorption in natural rocks. We evaluated reported sorption capacities and their variability across different lithologies alongside the influencing parameters and the occurrence of hysteresis. Additionally, we modeled all available data using multiple isotherm models to identify the best-fitting formulations. By synthesizing results across diverse methods and geological settings, we identify where physical sorption–desorption is likely to matter, where it is negligible, and what this means for understanding hydrogen transport and retention in the subsurface. Additionally, we provided practical implications of adsorption–desorption, identified critical data gaps, and proposed future research directions to advance the understanding of hydrogen behavior in geological formations.

• Nooraiepour, Mohammad; Dąbrowski, Karol M.; Masoudi, Mohammad; Kuczyński, Szymon; Song, Zezhang & Lothe, Ane Elisabet [Show all 7 contributors for this article] (2025). Geological CO2 storage assessment in emerging CCS regions: Review of sequestration potential, policy development, and socio-economic factors in Poland. International Journal of Greenhouse Gas Control. ISSN 1750-5836. 148, p. 1–25. doi: 10.1016/j.ijggc.2025.104524. Full text in Research Archive Show summary

  Emerging carbon capture and storage (CCS) markets face critical challenges in developing systematic methodologies to assess geological CO2 storage potential under conditions of limited data availability, evolving regulatory frameworks, and nascent infrastructure development. This study establishes an integrated assessment framework for lower-maturity CCS regions that combines geological characterization, storage capacity assessment, regulatory analysis, and socio-economic evaluation through a structured approach adaptable to diverse global contexts. Poland serves as a representative case study, with its coal-reliant economy exemplifying the decarbonization challenges facing emerging regions while meeting European Union climate mandates, and its geological setting offering substantial sequestration opportunities across three major sedimentary regions. Through multidisciplinary analysis synthesizing scattered geological data, policy developments, CCUS value chain dynamics, and stakeholder perspectives, we systematically evaluate CO2 storage potential and demonstrate framework application. Analysis reveals that onshore saline aquifers and depleted hydrocarbon fields provide significant storage capacity, while offshore Baltic Basin sites face logistical and environmental regulatory constraints. Current assessments encounter limitations including sparse data, restricted research access, and inadequate industry-academia collaboration, preventing basin-scale analyses from advancing to higher storage readiness levels and undermining business decision-making reliability. This study contributes a replicable methodology extending beyond Poland to lower-maturity CCS regions worldwide, providing decision-makers with tools for storage assessment, policy development, and stakeholder engagement that support evidence-based deployment strategies. Success in emerging markets requires coordinated advancement across technical characterization, regulatory clarity, infrastructure development, and public engagement, with transparent governance and inclusive community participation as critical enablers for sustainable CCS implementation.

• Barrabino, Albert; Auflem, Helene Berntsen; Masoudi, Mohammad; Holt, Torleif; Bjørkvik, Bård Johan Arnt & Grimstad, Alv-Arne (2025). Effect of the concentration of commercial partially CO2-soluble surfactants on foam strength. Geoenergy Science and Engineering. ISSN 2949-8929. 257(Part A), p. 2–2. doi: 10.1016/j.geoen.2025.214223. Full text in Research Archive Show summary

  Injection of CO2 foam is an emerging technology for CO2 mobility control. When searching for suitable surfactant system for maximum effect of the foam application it is necessary to consider deployment methods (dissolved in brine or in CO2) and ways to avoid loss of foam strength away from the injection well. Loss of strength is partially related to concentration depletion caused by surfactant adsorption and partitioning into formation brine. Here, two non-ionic surfactants with different CO2 solubilities were studied in steady-state core flooding experiments with co-injection of CO2 and surfactant solution with varying concentrations. For each surfactant concentration apparent viscosities were calculated from the measured differential pressures. The surfactant Brij L23 had a low partition coefficient at the experimental conditions used, meaning that little surfactant was found in the CO2. With this surfactant, foam was formed for low concentrations. The other surfactant, Tergitol TMN 10, was more CO2 soluble, and the partition coefficient increased when the pressure was increased. As a result of the pressure increase more surfactant partitioned into the CO2 and a higher concentration of surfactant was needed to form strong foam. The experimental observations are explained as a result of the surfactant partitioning and are related to the critical micelle concentration of surfactant in brine. Additional measurements were made to characterise the rheology of the CO2-brine interface for the different surfactant systems. It was shown that the interface was more flexible for the systems and conditions where strong foam was observed in the core flooding tests. The observation that surfactant systems with stronger partitioning into CO2 required higher concentrations to form strong foam, and also collapsed more rapidly for decreasing surfactant concentrations, seems to reject a proposition that high CO2 solubility is favourable for expanding the reservoir zone where foam is generated. This indicates that the search for methods for effective CO2 mobility control should concentrate on surfactants that are mainly water soluble. © 2025 The Authors

• Dąbrowski, Karol; Nooraiepour, Mohammad; Masoudi, Mohammad; Smulski, Rafał; Hellevang, Helge & Nagy, Stanisław (2025). Understanding Salt Precipitation Dynamics during CO2 Injection into Saline Aquifers using Microfluidic Experiments. In EAGE (Eds.), 86th EAGE Annual Conference & Exhibition, June 2-5, 2025, Toulouse, France. European Association of Geoscientists and Engineers (EAGE). doi: https:/www.earthdoc.org/content/papers/10.3997/2214-4609.202510377. Full text in Research Archive Show summary

  This study investigates salt precipitation dynamics using microfluidic experiments, simulating CO2-brine flow in porous media. The results show that salt crystallization is influenced by factors such as capillary backflow, fluid flow, and the interaction between CO2 and brine. Salt precipitation occurs not only where brine was initially present but also in upstream areas due to capillary flow dynamics, highlighting the complexity of these processes. Variations in salinity and flow rates further affect the crystallization behavior, influencing the size, shape, and distribution of salt deposits. These findings emphasize the need for a comprehensive understanding of crystallization mechanisms to improve CO2 sequestration strategies and mitigate unwanted salt precipitation in saline aquifers. Incorporating spatial variability and flow dynamics into models will enhance predictive capabilities and guide operational strategies.

• Masoudi, Mohammad; Nooraiepour, Mohammad; Blom, Richard; Xi, Kelai; Cerasi, Pierre & Hellevang, Helge (2025). Evaluating Hydrogen Sorption in Shale: Effects of Mineral Composition and Sample Treatment. In EAGE (Eds.), 86th EAGE Annual Conference & Exhibition, June 2-5, 2025, Toulouse, France. European Association of Geoscientists and Engineers (EAGE). doi: https:/www.earthdoc.org/content/papers/10.3997/2214-4609.202510554. Full text in Research Archive Show summary

  Understanding hydrogen adsorption on clay minerals is vital for optimizing hydrogen energy applications, including storage, natural hydrogen exploration, and also waste containment. However, safety concerns such as high diffusivity and invisible flame risks limit data on hydrogen’s interaction with various natural settings. This study presents the hydrogen adsorption capacities of four clay-rich shale samples from the Norwegian Continental Shelf (NCS) and three pure clay fractions. Utilizing a high-pressure gas adsorption analyzer, we obtained hydrogen sorption isotherms and found that non-dried clay samples had lower hydrogen sorption due to competition with water molecules. The sorption data were analyzed using Freundlich, Langmuir, and Toth models, with the Freundlich model providing the best fit. These findings highlight the complexities involved in hydrogen interactions with natural materials and underscore the need for careful modeling and analysis.

• Nooraiepour, Mohammad; Polański, Krzysztof; Masoudi, Mohammad; Bohloli, Bahman & Hellevang, Helge (2025). CO2-Induced Salt Crystallization in Sandstone Reservoirs: Significance for Mechanical Properties and Containment in Saline Aquifers. In EAGE (Eds.), 86th EAGE Annual Conference & Exhibition, June 2-5, 2025, Toulouse, France. European Association of Geoscientists and Engineers (EAGE). doi: https:/www.earthdoc.org/content/papers/10.3997/2214-4609.202510772. Full text in Research Archive Show summary

  Effective predictive modeling of CO₂ storage sites requires a comprehensive understanding of the physico-chemical processes and the challenges of scaling up operations. In high-salinity aquifers, CO₂ injection can significantly reduce injectivity due to pore clogging from salt precipitation. This study investigates the effects of CO₂-induced salt crystallization on the geomechanical properties of sandstone reservoirs. We examine the geochemical and mechanical coupling effects through CO₂-brine-rock interactions, utilizing two experimental paths: treatment with (a) CO₂-acidified brine and (b) supercritical injection leading to salt crystallization. High-pressure, high-temperature (HPHT) triaxial tests were conducted on Boise Buff (BB) and Torrey Red (TR) sandstones, representative of North Sea CO₂ storage candidates. The results showed up to a 50% reduction in Young’s and shear moduli, with TR sandstones being more susceptible due to their lower porosity and higher stiffness. An increase in ductility suggests mechanical weakening and potential storage integrity risks. These findings highlight the containment and integrity challenges posed by salt crystallization in (hyper)saline aquifers beyond injectivity issues, emphasizing potential mechanical failure risks due to pressure buildup. The study underscores the importance of incorporating geochemical interactions into CO₂ storage assessments and reservoir management strategies to mitigate these risks.

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• Lothe, Ane Elisabet; Masoudi, Mohammad; Bergmo, Per Eirik Strand; Nybø, Roar & Torsvik, Annika (2026). OMAE 2026 in Japan: Presenting energy efficient drainage, digital solutions, and more – LowEmission. Full text in Research Archive Show summary

  The OMAE 45th International Conference on Ocean, Offshore and Arctic Engineering is a premier conference for engineers, researchers, and technical specialists. This year, the conference took place in Tokyo with 1200 participants from more than 40 countries. And six of the participants were researchers from LowEmission.

• Nugrahaningtyas, Anisa; Masoudi, Mohammad; Bjørkvik, Bård Johan Arnt; Berg, Carl Fredrik & Net, Antje van der (2026). The Development of a Powder-Flotation Protocol for Rapid Screening of Aging- and Cleaning-Induced Wettability Alterations in Sandstone. doi: 10.5281/ZENODO.22123444. Full text in Research Archive
• Masoudi, Mohammad (2026). Lined Rock Caverns: What? Why? and How? — Exploring the Future of Underground Energy Storage. Full text in Research Archive
• Masoudi, Mohammad (2025). Hydrogen Adsorption-Desorption: Key Factors and Significance. Full text in Research Archive
• Nooraiepour, Mohammad; Masoudi, Mohammad; Derluyn, Hannelore; Senechal, Pascale; Moonen, Peter & Hellevang, Helge (2025). Role of Continuous Brine Access on Salt Precipitation Dynamics ─ Implications for Injectivity and Containment Integrity during Geological CO2 Storage. doi: https:/deca.upc.edu/ca/projectes/cryspom/abstracts-cryspom25.pdf/view. Full text in Research Archive Show summary

  Geological carbon storage emerges as a critical strategy for mitigating climate change via capturing and storing human-made CO₂ emissions. Salt precipitation during CO₂ injection in saline aquifers can cause pore clogging near the wellbore, reducing permeability and increasing pressure buildup, which may find significant consequences for injectivity, containment integrity, and the overall safety and efficiency of CO₂ storage operations. While increasingly more literature focuses on CO₂-induced salt precipitation, the underlying physics, growth dynamics, and fluid-solid interface behavior remain elusive. This study investigates the role of continuous brine access on pore-scale salt precipitation dynamics, significance for self-enhancing growth nature, and its broader implications for injectivity and containment criteria. Using laboratory techniques, including microfluidics, a Hele-Shaw cell, a flow-through system, a large-scale sandbox setup, and a triaxial geomechanical cell we explore the mechanisms governing brine evaporation and salt crystal growth, their pore occupancy and chemo-mechanical couplings. A key finding is the critical role of continuous brine sources, which significantly alter salt nucleation and growth dynamics by controlling solute availability and continuity through water film movement. Laboratory results reveal substantial salt accumulation near the injection port, emphasizing the importance of solute vailability in exacerbating salt accumulation severity. Two mechanisms accelerate growth dynamics. First, evaporation shifts the gas-liquid interface from larger to finer pores, expanding the surface area for brine evaporation and salt formation. Second, hydrophilic, hygroscopic halite crystals, nucleating on existing precipitates as secondary substrates via probabilistic nucleation, amplify reactive surface area and create a feedback loop. Salt crystallization can weaken reservoir rock, reducing mechanical strength and increasing susceptibility to shear failure. This weakening, evidenced by reduced Young’s and shear moduli, may lower the fracture gradient, posing a risk of unintentional fracturing during injection. By elucidating the role of continuous brine access on precipitation dynamics and the interplay of hydro-mechanical-chemical processes, the research offers insights for optimizing injection strategies and enhancing containment integrity. The findings underscore the need to incorporate these mechanistic aspects into reservoir-scale models to predict better and manage the impacts of salt precipitation on subsurface injection operations.

• Nooraiepour, Mohammad; Masoudi, Mohammad & Hellevang, Helge (2025). Salt precipitation dynamics in saline aquifers during geological CO2 storage: Role of continuous brine access and its implications for injectivity and containment integrity. Water-rock interaction: the International Symposium on Water-Rock Interaction : Proceedings. Full text in Research Archive

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