A method of identifying inflow locations along a wellbore includes obtaining an acoustic signal from a sensor within the wellbore, determining a plurality of frequency domain features from the acoustic signal, and identifying, using a plurality of fluid flow models, a presence of at least one of a gas phase inflow, an aqueous phase inflow, or a hydrocarbon liquid phase inflow at one or more fluid flow locations. The acoustic signal includes acoustic samples across a portion of a depth of the wellbore, and the plurality of frequency domain features are obtained across a plurality of depth intervals within the portion of the depth of the wellbore. Each fluid flow model of the plurality of fluid inflow models uses one or more frequency domain features of the plurality of the frequency domain features, and at least two of the plurality of fluid flow models are different.

The present disclosure relates to a three-dimensional ground model generation and an automated earthwork target model generation system based on a parameter input.

A seismic interpretation method for identifying subsurface hydrocarbon bearing traps of Eocene/Paleocene age in valley fill depositional systems comprising as computer implemented modeling software and processed seismic data. The valley dispositional system is further defined by identifying field stratigraphy and erosional trapping mechanisms and confirming structural closure. The method further includes identifying structural aspects caused by sagging, rollover, and determining the presence of high amplitude events in the erosional trap.

A method, apparatus, and program product model an oilfield asset by selecting, for each of multiple sectors of the oilfield asset, a sector model from among a collection of sector models, building a multi-resolution integrated asset model of the oilfield asset using the selected sector model for each of the sectors, and performing a computer simulation using the multi-resolution integrated asset model. The collection of sector models for each sector includes multiple sector models modeled at varying resolutions. In addition, the multi-resolution integrated asset model includes a surface network model that couples the selected sector models to one another. As such, different sectors of an oilfield asset may be modeled at varying resolutions to balance accuracy and turnaround time when performing integrated oilfield asset modeling.

The present invention is related to a method for estimating the fractured volume in a reservoir domain, said fractured volume generated by injecting a high pressure fluid into the reservoir domain. The high pressure fluid generates new fractures allowing a more effective drainage of porous rocks, generally identified as geological material, containing oil or gas. As a result, the effective reservoir volume increases. According to embodiments of the invention, the method provides a dynamic estimation of the fractured volume taking into account the evolution of the rock and the fractures. In other embodiment, the evolution of the fractured volume is estimated by generating an envelope surrounding the induced fractures allowing a better estimation of the fractured volume.

A three-dimensional grid of a hydrocarbon reservoir can be received. The three-dimensional grid can include a plurality of cells, each cell of the plurality of cells can include a first index value, a second index value, and a third index value. The first index value, the second index value, and the third index value of each cell can together uniquely identify each cell of the plurality of cells. Each cell can further include at least one parameter measured from the hydrocarbon reservoir. A hydrocarbon saturation distribution of the hydrocarbon reservoir can be determined using a saturation height function and the at least one parameter of each cell of the plurality of cells. The hydrocarbon saturation distribution can include a cell hydrocarbon saturation estimate for each cell of the plurality of cells. The hydrocarbon saturation distribution can be provided. Related apparatus, systems, techniques and articles are also described.

A system and method for specifying a composition for a frac fluid including varying crosslinker concentration and high-temperature stabilizer concentration to determine a discrete fracture network (DFN) and hydrocarbon production correlative with the DFN.

Technologies related to training machine-learning-based surrogate models for phase equilibria calculations are disclosed. In one implementation, an equation of state (EOS) for each of one or more regions of a reservoir is determined based on results of one or more pressure, volume, or temperature (PVT) experiments conducted on samples of downhole fluids obtained from one or more regions of the reservoir. Compositions of the samples of the downhole fluids are determined and spatially mapped based on interpolations between the one or more regions of the reservoir. One or more PVT experiments are simulated for the spatially mapped compositions of the downhole fluids using the determined EOS to create a compositional database of the reservoir. One or more machine-learning algorithms are trained using the compositional database, and the trained one or more machine-learning algorithms are used to predict phase stability and perform flash calculations for compositional reservoir simulation.

The invention relates to a method of determining a dominant hydrocarbon migration mechanism in a sedimentary basin, using a numerical basin simulation simulating a hydrocarbon migration according to at least two migration mechanisms and measurements of physical quantities performed in the basin. A numerical basin simulation and a gridded representations of different states is used to determine a contribution of each hydrocarbon migration mechanism for each state for the cells of the gridded representation of this state.

A method and system, including a device having a processor and instructions stored on a non-transitory computer readable medium. In the system and method, data is identified and collected that is required to simulate a geographical area. The data is input into a simulation engine that runs a simulation of the geographical area. A scenario is identified to apply to the simulation, wherein the scenario is identified through employment on non-simulated data. The scenario is applied to the simulation by revising the data that is input to the simulation engine.