Publications

Basin modeling is used to gain a better understanding of the interaction between the elements and processes of the petroleum system in the study area. The modeling used in this research is two-dimensional (2D). The modeling is using the Temis2D software ver. 4.0.2, and validate modeling outputs with data from laboratory measurements such as Vitrinite Reflectance (Ro) and Temperature (BHT). This study was located in the offshore between the Timor Island and Australian boundary, which passes through the Ashmore Platform and Bena Basin. The source rock in the model is interpreted as being deposited from the Middle Triassic to the Early Jurassic or from the Ladinian to before the Aalenian age. Deposition of organic material is modelled in the basin-deep or deep areas at each age of deposition. Burial history models in the study area illustrate simply the history of rock sedimentation influenced by tectonic events that occurred during the initial sedimentation of the oldest sedimentary rocks (Top Tatarian at 259 Ma) to the present (0 Ma). In this area, the Ladinian shale maturity level is at peak to late mature (0.8–1.1% Ro). In the NW area, which is close to the trough, Ladinian shale has a post mature maturity level (0.9-1.5% Ro). Carnian shale in the SE-NW region has early to peak mature maturity (0.6-0.8% Ro). Aalenian shale is at an immature to early mature level (0.5-0.7% Ro) in this composite line. Current Transformation Ratio models show that kerogens in the Ladinian shale source rock in composite line (SE-NW) have been 50% to 100% transformed into hydrocarbons at the trough area. The kerogen transformation ratio in Carnian shale rock at the trough area has changed from around 20% to 70% to become hydrocarbons, while Jurassic shale in the trough (NW) area has changed by around <10%, while it has not changed in other areas.