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We measured the streaming potential coupling coefficient of natural saturated and unsaturated carbonate rocks. Saturation was achieved with NaCl brines with salinities ranging from 2 ´ 10 −3 to 2.0 mol L −1 . The magnitude of the coupling coefficient increased with decreasing salinity, similarly to the trend observed for sandstones. The permeability had a low impact on the values of the streaming potential coupling coefficient at high and low salinity. The zeta potential was calculated at full saturation using a modified version of the Helmholtz-Smoluchowski equation that accounts for surface electrical conductivity. Under atmospheric conditions, the magnitude of the zeta potential decreased with the increase in salinity. We also explored the relationships between the streaming potential coupling coefficient and water saturation in three partially saturated limestones using a steady-state flow experiment. We found good agreement between the van Genuchten approach and experimental data, and fitted both the relative permeability and capillary pressure curves with the same value of the van Genuchten exponent m v . We validated the predictive water relative permeability model described by Revil in water-wet rocks when the second fluid phase is non-polar.

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-Unconventional resources such as tight, fractured and hybrid shale gas and oil plays as well as oil or kerogen shale systems, are considered exploitable self-contained source and reservoir rocks. A better understanding of the thermal cracking of sedimentary organic matter, hydrocarbons generation, expulsion, storage and retention mechanisms constitutes a key point, estimating the oil and gas in-place, free or adsorbed, for their exploration and exploitation. Herein, we introduce a new "ready to use" method of analysis and interpretation for the Rock-Eval 6 device for better assessment of free or sorbed hydrocarbons in unconventional shale plays. This method was developed at IFP Energies nouvelles (France) and was tested on 15 actual or potential unconventional shale samples from Silurian Shale (Algeria), Mississippian Barnett Shale (USA), Early Jurassic Shale (France), Late Jurassic Bazhenov Shale (Russia) and Eocene Green River Shale at different thermal maturity stages. Results indicate a better quantification of free and/or sorbed hydrocarbons (Sh0 and Sh1 peaks) as well as a more accurate determination of the RockEval T max maturity parameter.Résumé -Nouvelle méthode de pyrolyse Rock-Eval pour la caractérisation des hydrocarbures de roches mères non conventionnels -Les ressources non conventionnelles, en particulier les hydrocarbures de roches mères et les schistes bitumineux sont actuellement considérées comme des roches réservoirs pétroliers exploitables. Une meilleure compréhension sur le craquage thermique de la matière organique sédimentaire, sur les mécanismes de production/génération, d'expulsion, de stockage et de rétention des hydrocarbures constitue un point essentiel à la fois pour l'estimation mais également pour l'exploration et l'estimation du pétrole et du gaz en place (libre ou adsorbé) présents dans ces systèmes. Ici, nous présentons une nouvelle méthode d'analyse et d'interprétation pour le Rock-Eval 6 permettant une meilleure estimation/évaluation des hydrocarbures libres ou adsorbés au sein d'une roche mère non conventionnelle. Cette méthode, développée à l'IFP Energies nouvelles (France), a été élaborée et testée sur 15 échantillons de schistes actuels ou potentiels provenant : du Silurien Shale (Algérie), du Mississippien Barnett Shale (USA), du Jurassique Inférieur du Bassin de Paris (France), du Jurassique Supérieur Bazhenov Shale (Russie) et de l'Eocène Green River Shale (USA) et ce, à des stades différents de maturité thermique. Les résultats

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