Fault seal modellingthe influence of fluid 1 properties on fault sealing capacity in hydrocarbon 2 and CO 2 systems 3 This is non peer-reviewed original version of the manuscript that has been 4 submitted for publication in Petroleum Geoscience. The final published 5 version is available via the 'Peer-reviewed Publication DOI' link on the right-5 6 hand side of the webpage. 7 Abstract 17Fault seal analysis is a key part of understanding the hydrocarbon trapping 18 mechanisms in the petroleum industry. Fault seal research has also been expanded 19 to CO2-brine systems for the application to Carbon Capture and Storage (CCS). The 20 wetting properties of rock-forming minerals in the presence of hydrocarbons or CO2 21 are a source of uncertainty in the calculations of capillary threshold pressure, which 22 defines the fault sealing capacity. Here we explore this uncertainty in a comparison 23 study between two fault-sealed fields located in the Otway Basin, south-east 24Australia. The Katnook field in the Penola Trough is a methane field, while Boggy 25Creek in Port Campbell contains a high-CO2/methane mixture. Two industry 26 standard fault seal modelling methods (Yielding et al., 2010;Sperrevik et al., 2002) hydrocarbons or CO2 sequestration, the subject of interest is not the exact threshold 56 capillary pressure of a certain fault but rather the implications of that value to the 57 desired industrial activity. In exploration, this is applied to estimate maximum column 58 height and determine the economic viability of production. It is therefore important to 59 3 estimate how the uncertainty associated with the predictive method impacts the 60 prospect. In the context of CO2 storage, threshold capillary pressure is used to 61 define the reservoir storage capacity. In this case the aim is not to overpressure the 62 fault and thus cause leakage. The practical use of fault seal modelling therefore 63 requires a good understanding of the uncertainty associated with the two different 64 approaches. 65The interfacial tension (IFT) and the contact angle (CA) are the main fluid-66 specific properties controlling the capillary seal and the key parameters used in both 67 hydrocarbon and CO2 studies. The wetting properties of various rock-forming 68 minerals are different for CO2 and hydrocarbons, which has caused a concern that 69 the seal rocks proven to retain hydrocarbon columns might be less sealing to CO2 70 (Chiquet et al., 2007b;Daniel and Kaldi, 2009; Guariguata-Rojas and Underhill, 71 2017;Tenthorey et al., 2014). A recent study by Miocic et al. (2019) explored the 72 interplay between uncertainties in CA, IFT and fault rock composition in the CO2-73 brine system. The results highlighted that higher phyllosilicate content in the fault 74 rock reduces the threshold capillary pressure in the CO2-brine system due to the 75 wettability of the clay minerals in the presence of CO2, especially at depths > 1 km. 76Our understanding of CA and IFT primarily relies on empirical measurements, 77 meaning that significant unc...