Search for a command to run...
Abstract In offshore oil and gas fields, well spacing is large, which can result in significant uncertainties when constructing a petrophysical model based on limited well and seismic data. By utilizing the principles of sequence stratigraphy, forward stratigraphic modeling (FSM) is a powerful tool to simulate the sedimentary filling process. This paper aims to reduce these uncertainties in the Pliocene deltaic system of F3 block by integrating FSM and geostatistics. First, the sequence stratigraphy of the study area is interpreted using well and seismic data. Next, the FSM is simulated with paleo-topography, global sea-level curve, sediment supply and tectonic rate. The primary uncertainties are the sediment composition in paleo-topography and depth-dependent diffusion function. A sensitivity analysis is done to quantify the impact of these uncertain parameters on the FSM. Finally, geostatistics are employed to create two gamma ray (GR) properties: the first derived from the seismic attribute, and the second constructed through the FSM. These GR properties are then compared using blind well data. The FSM successfully reproduces the stacking pattern within the study area. Meanwhile, the strata thickness from the FSM not only aligns with well data but also exhibits trend patterns between wells that are consistent with seismic interpretations. After analyzing the sensitivity of primary uncertain parameters, compared to fine sand and silt, the change of coarse sand and clay fraction has more impact on the strata thickness from the FSM. Meanwhile, different depth-dependent functions significantly affect the geomorphology in the FSM. Finally, the GR property derived from the seismic attribute fails to accurately reproduce the vertical trend at the blind well location and demonstrates poor lateral continuity. In contrast, the GR property constructed through the FSM aligns well with the vertical trend at the blind well location and exhibits significantly improved lateral continuity. The findings of this study effectively reduce the uncertainty in the petrophysical modeling of F3 block, despite limited well and seismic data. Additionally, the sensitivity analysis offers valuable insights for enhancing the FSM. Comparisons between GR properties derived from seismic attributes and the FSM clearly demonstrate the FSM can better capture subsurface lateral continuity. Moreover, this integrated approach can be applied to other projects involving deltaic systems.