Abstract: A method for managing a reservoir, including: receiving a plurality of geological data values associated with the reservoir; identifying a plurality of catchment areas associated with the reservoir based on the plurality of geological data values; identifying a plurality of spill points for the reservoir based on the plurality of catchment areas; identifying a plurality of reservoir traps for the reservoir based on the plurality of spill points and the plurality of catchment areas; and determining a plurality of effective trap sizes and a plurality of effective catchment area sizes based on the plurality of reservoir traps and the plurality of catchment areas.

Abstract: A method for performing a field operation within a geologic basin having rock formations and a reservoir that includes fluids includes generating, by forward modeling using a petroleum system model (PSM), an estimate of a fluid property distribution of a fluid within the reservoir of the geologic basin. The method further includes detecting, from fluid samples, a fluid property gradient within the geologic basin. The fluid samples are extracted from within at least one wellbore drilled through the rock formations. The method further includes, comparing the estimate of the fluid property distribution with the detected fluid property gradient to generate a comparison result, iteratively adjusting, based on the comparison result, the PSM to generate an adjusted PSM, and performing, based on the adjusted PSM, the field operation within the geologic basin.

Abstract: A method for performing a field operation within a geologic basin includes obtaining two basin snapshots of the geologic basin, performing a particle dynamics simulation of the geologic basin using at least the two basin snapshots to generate an intermediate basin snapshot, performing, using at least the intermediate basin snapshot as a constraining condition, a basin simulation of the geologic basin to generate a simulated evolution of the basin rock geometry within the geologic basin, and performing, based on the simulated evolution of the basin rock geometry, the field operation within the geologic basin.

Abstract: A method for performing a field operation within a geologic basin having rock formations and a reservoir that includes fluids includes generating, by forward modeling using a petroleum system model (PSM), an estimate of a fluid property distribution of a fluid within the reservoir of the geologic basin. The method further includes detecting, from fluid samples, a fluid property gradient within the geologic basin. The fluid samples are extracted from within at least one wellbore drilled through the rock formations. The method further includes, comparing the estimate of the fluid property distribution with the detected fluid property gradient to generate a comparison result, iteratively adjusting, based on the comparison result, the PSM to generate an adjusted PSM, and performing, based on the adjusted PSM, the field operation within the geologic basin.

Abstract: A method for modeling a migration of hydrocarbon fluids. The method may include decomposing, by operation of a processor, a domain of a basin model to produce a first plurality of cells having a permeability below a threshold value and a second plurality of cells having a permeability above the threshold value. A first migration analysis may be performed to analyze a relatively slow migration starting in the first plurality of cells. A second migration analysis may be performed to analyze a relatively faster migration starting m the second plurality of cells.

Abstract: A method, apparatus, and program product determine an effective trap size for reservoir traps of an oil and gas reservoir. Geological data is analyzed to determine structural spill points. Based on the structural spill points and the geological data reservoir traps are identified. An effective trap size for at least some of the reservoir traps of the reservoir is determined based on the structural spill points and the geological data.

Abstract: Methods, systems, and computer-readable media for compressing topological grid data for layered geological strata are described. The techniques include obtaining topological grid data for a layered geological structure, where the topological grid data includes a plurality of cell representations, a majority of the cell representations including at least one data value, where the topological grid data includes at least one pinch-out cell representation lacking a data value. The techniques also include interpolating a data value for the at least one pinch-out cell representation to produce interpolated topological grid data. The techniques also include transforming the interpolated topological grid data to obtain frequency domain interpolated topological grid data. The techniques also include truncating ordered coefficients of the frequency domain interpolated topological grid data to obtain truncated frequency domain interpolated topological grid data.

Abstract: A method can include providing finite elements described with respect to a horizontal coordinate axis and a vertical coordinate axis to model a sedimentary basin, identifying a finite element having a horizontal boundary intersected by a fault, subdividing the finite element into two finite elements, and representing the fault along a boundary between the two finite elements. Various other apparatuses, systems, methods, etc., are also disclosed.

Abstract: A method for estimating properties of fluids in rock formations at selected locations within a geologic basin includes generating an initial model of the basin. The model includes as output spatial distribution of at least rock formation mineral composition, rock formation porosity and composition of fluids in the rock formation porosity. An initial estimate of fluid composition is generated for at least one rock formation at at least one selected location within the basin. A sample of fluid is extracted from pore spaces of the at least one rock formation from within a wellbore drilled therethrough. Composition of the fluid sample is analyzed from within the wellbore. The initial model of the basin is adjusted such that model predictions substantially match the analyzed fluid composition. The adjusted model is used to generate an initial estimate of fluid composition at at least one additional geodetic location within the basin.