Various embodiments described herein provide methods of hydrocarbon management and associated systems and/or computer readable media including executable instructions. Such methods (and by extension their associated systems and/or computer readable media for implementing such methods) may include obtaining geophysical data (e.g., seismic or other geophysical data) from a prospective subsurface formation (that is, a potential formation or other subsurface region of interest for any of various reasons, but in particular due to potential for production of hydrocarbons) and using a trained machine learning (ML) system for direct hydrocarbon indicators (DHI) analysis of the obtained geophysical data. Hydrocarbon management decisions may be guided by the DHI analysis.

Various embodiments described herein provide methods of hydrocarbon management and associated systems and/or computer readable media including executable instructions. Such methods (and by extension their associated systems and/or computer readable media for implementing such methods) may include obtaining geophysical data (e.g., seismic or other geophysical data) from a prospective subsurface formation (that is, a potential formation or other subsurface region of interest for any of various reasons, but in particular due to potential for production of hydrocarbons) and using a trained machine learning (ML) system for direct hydrocarbon indicators (DHI) analysis of the obtained geophysical data. Hydrocarbon management decisions may be guided by the DHI analysis.

A method can include receiving mechanical information of a geologic environment and location information of natural fractures of the geologic environment; using a model of the geologic environment, calculating at least strain associated with hydraulic fracturing in the geologic environment; calculating at least microseismicity event locations based at least in part on the calculated strain; calibrating the model based at least in part on the calculated microseismicity event locations and based at least in part on measured microseismicity information associated with the geologic environment to provide a calibrated model; and, using the calibrated model, determining an increase in reactivated fracture volume associated with hydraulic fracturing in the geologic environment.

A numerical simulation and parameter optimization method for volumetric fracturing of an unconventional dual medium reservoir includes the following steps: based on the theory of dual-medium pore elasticity, in consideration of the friction effect between fractures, developing a viscoelastic-plastic damage model of hydraulic fractures based on explicit time integral; simulating random intersection and bifurcation of hydraulic fractures encountering with natural fractures by adopting a method of embedding zero-thickness fracture units in the inner boundaries of computational model grids, and establishing a mathematical model of hydraulic fracture expansion of volumetric fracturing in the unconventional dual-medium reservoir; compiling a finite element program for complex multi-fracture fracturing and competitive expansion during volumetric fracturing of the unconventional reservoir, and establishing a hydraulic fracturing finite element model of a casing-cement ring-perforation hole in cluster-reservoir matrix containing natural fractures.

A system and method for pit design that that operates directly on a geological model without creating a three dimensional block model thereby minimizing modeling dilution. A resource in a deposit may be divided into a set of base resource units that closely conform to the resource geometry and value distribution and that can be mined by the equipment assumed to perform the excavation. A resource increment (RI) is defined by a base resource unit and any resource and waste over the base resource unit which is assumed to be excavated in conformance with slope stability and safe practices forming an approximation of a truncated inverted cone. A systematic sorting and grouping process of the RIs iterates down a list of RIs and identifies RIs and/or RI groups that add value to the pit while excluding RIs and/or RI groups that do not add value. The sorting and grouping process operates on the recognition that, for RIs analyzed later in the RI list, the cost of intersections of waste overlaying the RIs base resource unit is carried by RIs analyzed earlier in the list. The sorting and grouping process allows intersecting RIs to be evaluated, grouped into RI groups, and either included or not included in the pit so that a maximum valued pit is defined. One aspect of the novel sorting and grouping process is the identification and grouping of interdependent RIs and RI groups. Another novel aspect of this pit design system is the application of over lapping RI bases with size defined large enough to represent the minimal accessible mining space for the equipment proposed. Larger sized bases should lead to reduction in the complexity of intersecting RIs and computational time. The end result is a model of the pit including a list of RIs and/or RI groups to include in the pit and resource and/or reserve statements.

Embodiments of methods, systems, and computer-readable media for coupling two or more simulators to simulate a coupled multi-physics model of a subsurface formation are provided. A coupling framework loads one or more simulators as shared libraries into a common process and a common memory space with a first simulator to create the coupled multi-physics model of the subsurface formation. During simulation, the coupling framework controls data exchange between the first simulator and the other simulator(s) through the common memory space and controls execution of the first simulator and the other simulator(s) responsive to the common process. In the event of two-way coupling, the coupling framework can receive feedback from the other simulator(s) and alter execution of the first simulator. In the event of grid misalignment, the coupling framework can map data between the first simulator and the other simulator(s) such as in a globally conservative (e.g., mass, energy, etc.) manner.

A system and method to determine effective fracture surface-area per cluster of hydraulic fractures of a hydraulically-fractured well by estimating total effective fracture-area associated with a wellbore and estimating relative distribution of effective fracture surface-area along the wellbore.

A method includes receiving image data that is to be recognized by the at least one neural network. The image data is representative of a fault within a subsurface volume. The image data includes three-dimensional synthetic data. The method also includes generating an output via the at least one neural network based on the received image data. The method also includes comparing the output of the at least one neural network with a desired output; and modifying the neural network so that the output of the neural network corresponds to the desired output.

Systems and methods for generating a fractured reservoir model include: receiving a seismic dataset of a surveyed subsurface; identifying a dynamic response of each parameter; selecting a subset of parameters from the set of parameters based on the dynamic response of each parameter; sampling an outer boundary of a parameter uncertainty domain; adjusting the range of values associated with each parameter of the subset based on the sampling; generating a geo-model based on the adjusted range of values associated with each parameter of the subset; generating a discrete fracture network model based on the geo-model; generating a scenario of a simulation model based on the discrete fracture network model and the geo-model; performing a forward simulation based on the scenario of the simulation model; determining that a misfit of the forward simulation is below a threshold by evaluating an objective function; and producing a model based on the forward simulation.

Systems and methods for generating and storing measurements in point and vector format for a plurality of formations of reservoirs. In one embodiment, the methods comprise generating a set of measurements corresponding to a plurality of formations, reservoirs, or wellbores; determining physical locations for the set of measurements, wherein the physical locations are represented in a point and vector representation; associating the vector representations with the determined physical locations, wherein the vector representations comprise at least a magnitude and a direction derived from the measurement; wherein the magnitude and direction tracks the physical location in space and time; manipulating the set of measurements such that a change in physical location is updated in the vector representation; generating a repository of vector representations accessible to determine an optimal completion design for a set of parameters for a subterranean formation.