37 citations as recorded by crossref.

1. Hydro-mechanical response of Opalinus Clay in the CO2 long-term periodic injection experiment (CO2LPIE) at the Mont Terri rock laboratory D. Sciandra et al. 10.1007/s40948-022-00442-x
2. Characterization of multiphase flow in shaly caprock for geologic CO2 storage H. Kim & R. Makhnenko 10.1016/j.advwatres.2023.104570
3. An approach for assessment of CO2 leakage using mechanistic modelling: CO2 injection in deep saline aquifer of Lithuanian basin in presence of fault and fractures S. Dangi et al. 10.21595/accus.2024.23889
4. Applications and future developments of the (thermo-) poro-elastic theory in geophysics M. Nespoli et al. 10.1016/j.earscirev.2024.104996
5. Characterization of heterogeneities in the sandy facies of the Opalinus Clay (Mont Terri underground rock laboratory, Switzerland) S. Lüth et al. 10.1093/gji/ggad494
6. Gas equilibrium membrane inlet mass spectrometry (GE-MIMS) for water at high pressure M. Brennwald et al. 10.5194/gi-13-1-2024
7. Reactivation of rate-and-state faults induced by CO2 injection: Effects of pore pressure diffusion and fluid pressurization Y. Zhang et al. 10.1016/j.jrmge.2025.03.002
8. Experimental measurements and characterization models of caprock breakthrough pressure for CO2 geological storage B. Chen et al. 10.1016/j.earscirev.2024.104732
9. Seismic anisotropy of Opalinus Clay: tomographic investigations using the infrastructure of an underground rock laboratory (URL) R. Esefelder et al. 10.1186/s00015-021-00398-2
10. Fluid pressure monitoring during hydraulic testing in faulted Opalinus Clay using seismic velocity observations M. Grab et al. 10.1190/geo2021-0713.1
11. A critical review of CO2 mineral trapping in sedimentary reservoirs – from theory to application: Pertinent parameters, acceleration methods and evaluation workflow S. Khandoozi et al. 10.1016/j.earscirev.2023.104515
12. Evolution of the Caprock Sealing Capacity Induced by CO2 Intrusion: A Simulation of the Dezhou Dongying Formation S. Yang & H. Tian 10.3390/en17215462
13. Assessment of CO2 leakage using mechanistic modelling approach for CO2 injection in deep saline aquifer of Lithuanian basin in presence of fault and fractures S. Dangi et al. 10.21595/bcf.2023.23619
14. Field-scale fault reactivation experiments by fluid injection highlight aseismic leakage in caprock analogs: Implications for CO2 sequestration Y. Guglielmi et al. 10.1016/j.ijggc.2021.103471
15. Deformation Behavior and Seismic Characteristics of Sandy Facies Opalinus Clay During Triaxial Deformation Under Dry and Wet Conditions V. Schuster et al. 10.1007/s00603-024-03802-z
16. Carbon dioxide capture, transport and storage supply chains: Optimal economic and environmental performance of infrastructure rollout V. Becattini et al. 10.1016/j.ijggc.2022.103635
17. Analysis of the effect of formation dip angle and injection pressure on the injectivity and migration of CO2 during storage J. Jing et al. 10.1016/j.energy.2023.128021
18. Frictional properties of Opalinus Clay: influence of humidity, normal stress and grain size on frictional stability N. Bigaroni et al. 10.1093/gji/ggac457
19. Investigation of different caprock morphologies on CO2 leakage and solubility trapping mechanism P. Punnam et al. 10.1038/s41598-025-03416-7
20. In-situ experiment reveals CO2 enriched fluid migration in faulted caprock U. Weber et al. 10.1038/s41598-023-43231-6
21. Performance of high-resolution impact and vibration sources for underground seismic exploration of clay formations at the scale of a rock laboratory B. Wawerzinek et al. 10.1093/gji/ggac283
22. Insights into the interaction of a shale with CO2 E. Stavropoulou & L. Laloui 10.5194/se-13-1823-2022
23. Potential for permanent CO2 sequestration in depleted volcanic reservoirs in the offshore Campos Basin, Brazil G. Silva Ramos et al. 10.1016/j.ijggc.2023.103942
24. Integrated Thermo-Hydro-Mechanical Workflow for Modeling CO2 Storage with Fault Activation Risk Z. Wei et al. 10.2118/225428-PA
25. A quantitative approach for sealing capacity evaluation of caprock in candidate of aquifer gas storage S. Jia et al. 10.1007/s11356-023-26873-x
26. Analysis of hydrodynamic trapping interactions during full-cycle injection and migration of CO2 in deep saline aquifers Y. Wang et al. 10.1016/j.advwatres.2021.104073
27. Evaluation of possible reactivation of undetected faults during CO2 injection L. Blanco-Martín et al. 10.1016/j.ijggc.2022.103794
28. Transient evolution of permeability and friction in a slowly slipping fault activated by fluid pressurization F. Cappa et al. 10.1038/s41467-022-30798-3
29. Physical characterization of fault rocks within the Opalinus Clay formation L. Orellana et al. 10.1038/s41598-022-08236-7
30. Monotonic fluid injection induces fault instability and slip: A laboratory study J. Liu et al. 10.1016/j.enggeo.2025.108047
31. Coupling 3D geomechanics to classical sedimentary basin modeling: From gravitational compaction to tectonics A. Brüch et al. 10.1016/j.gete.2021.100259
32. Multi‐Layered Systems for Permanent Geologic Storage of CO2 at the Gigatonne Scale I. Kivi et al. 10.1029/2022GL100443
33. Challenges and opportunities in carbon capture, utilization and storage: A process systems engineering perspective M. Hasan et al. 10.1016/j.compchemeng.2022.107925
34. New experimental approaches enabling the continuous monitoring of gas species in hydrothermal fluids S. Giroud et al. 10.3389/frwa.2022.1032094
35. Chemo‐Mechanical Coupling in Fractured Shale With Water and Hydrocarbon Flow Q. Wenning et al. 10.1029/2020GL091357
36. CO2 Storage in deep saline aquifers: impacts of fractures on hydrodynamic trapping Y. Wang et al. 10.1016/j.ijggc.2021.103552
37. In situ hydromechanical responses during well drilling recorded by fiber-optic distributed strain sensing Y. Zhang et al. 10.5194/se-11-2487-2020