Abstract: A method for training a well model to predict material loss for a pipe string having a wall thickness and located within a borehole. The method may include measuring the wall thickness of a first pipe string at locations axially along the first pipe string with a logging tool at a first time. The method may also include measuring the wall thickness of the first pipe string at the locations with the logging tool at a second time. The method may further include training a first well model based on a machine learning (“ML”) algorithm to predict a predicted amount of material loss in the future for the first pipe string at a selected location using the wall thickness measurements at the first and second times and well operating condition information related to the first pipe string.

Abstract: A method for determining active constraint equations in a network of wells and surface facilities includes constructing at least one constraint equation for a connection in the network. Each constraint equation includes a respective slack variable and a respective slack variable multiplier. The method further includes constructing a base equation for the connection. The base equation includes the respective slack variable and another respective slack variable multiplier. The method further includes introducing a pseudo slack variable for another connection in the network such that a Schur complement, of a matrix of constraint and base equations dependent only on slack variable multipliers, is sparse. The method further includes solving for each respective slack variable using the Shur complement matrix. The method further includes adjusting a variable parameter of the network using results from solving for each respective slack variable.

Abstract: A system to provide on-demand fetching of sequential sets of seismic data to local memory from slower storage mediums prior to performing computing operations, such as horizon auto-tracking, amplitude extraction and seismic attribute generation. As a result, the performance of the storage infrastructure (e.g., hard drives, storage filer “file server” over network, etc.) is maximized and the local memory/cache speed is fully utilized to deliver optimal system performance even when working with large seismic datasets that exceed the storage capacity of the local memory.

Abstract: Tubular elasticity is applied to determine tubular wear volume. In general, a torque and drag model is applied to calculate the dynamic stretch of the inner tubular string (e.g., drill string). The dynamic stretch is then integrated into a casing wear model to improve the accuracy of the calculated wear and its corresponding position along the outer tubular string (e.g., casing string).

Abstract: Systems and methods to correct misties across multiple 2D seismic surveys using a correction solution calculated based only on the intersecting points between different surveys.

Abstract: The selection of a candidate formation realization(s) from a plurality of formation realizations may be done with a classification and regression tree (CART) analysis taking into account petrophysical and geological properties. For example, a method may include applying a CART analysis to a plurality of formation realizations using a first formation property as a predictor in the CART analysis, wherein the plurality of formation realizations are for a second formation property and are based on at least one measured formation property, thereby yielding an association between the first and second properties for each of the plurality of formation realizations; analyzing a strength of the association for each of the plurality of formation realizations; and selecting a candidate formation realization from the plurality of formation realizations based on the strength of the association. The identified candidate formation realization(s) may then be used to develop the parameters of subsequent wellbore operations.

Abstract: Tubular wear volume is determined using adjustable wear factors. The wear factors are applied as a function of the side force factor, friction factor, and/or temperature factor. The adjusted wear factors are then used to determine the tubular wear volume.

Abstract: Methods and systems are presented in this disclosure for semblance-based anisotropy parameter estimation using isotropic depth-migrated common image gathers. Far-offset image gathers can be generated from seismic data associated with a subterranean formation migrated based on an isotropic depth migration that uses an isotropic velocity model. Based on the far-offset image gathers, a plurality of semblance values can be calculated as a function of an anisotropy parameter of the subterranean formation for the different depths and the surface locations. Effective values of the anisotropy parameter of the subterranean formation can be then chosen that result in maxima of the plurality of semblance values for the different depths and the surface locations. Anisotropy model of the subterranean formation can be obtained based on the effective values of the anisotropy parameter.

Abstract: Method and system for optimizing production from an oil and gas reservoir includes selecting a geocellular grid representing at least one property of the reservoir, defining a data range for the property that reflects uncertainty regarding which values may be used for the property, defining a first reservoir simulation model, simulating production from the reservoir with the model using the at least one property, comparing the output of the simulated production from the reservoir with a predetermined criteria based on historical data, and modifying the property to a different value within the data range for the property if the predetermined historical criteria is not met. These steps may be repeated for at least two values for the property within the data range. The above may be repeated for a second reservoir model and the outputs of the simulated production for the models may then be ranked according to predefined criteria.

Abstract: Methods, computer readable medium, and systems for mapping geologic features are described. In one example, a selection of a template describing a theoretical geologic depositional profile is received. In addition, paleo-elevations and/or paleo-depths of actual geologic facies in an actual geologic depositional profile are received. A graphical map that represents the actual geologic depositional profile is generated by mapping the received paleo-elevations and/or paleo-depths onto the theoretical depositional profile.

Abstract: Methods and systems are presented in this disclosure for performing fast economic analysis of production by fracture-stimulated wells. A class of models can be defined by combining a simulated fracture geometry comprising a stimulated reservoir volume with accounting for fluid dynamics and phase transitions in the stimulated reservoir volume for modeling production in a plurality of reservoirs. An objective function related to the production in the plurality of reservoirs can be generated based on at least one model from the class of models. Parameters related to fracture stages of a fracture network can be then determined, based on the objective function, and communicated, via a computer network to a computing device, to be used for at least one of building or operating the fracture network in the reservoir.

Abstract: Systems and methods for mapping vertices from one coordinate system in an earth model to another coordinate system in a two-dimensional (2D) array without disrupting the topology of the vertices.

Abstract: A hydrocarbon field including thief zones can be modeled based on production history data and supplemental data constraining a thief-zone distribution across the field. In various embodiments, a numerical optimization approach involves creating a plurality of model thief-zone distributions with varying parameter values, parameterizing permeability maps obtained for the thief-zone distributions and aggregating across the thief-zone distributions to obtain distributions of coefficients associated with the parameterization, and then iteratively sampling the coefficient distributions, determining a permeability map of the model based on the selected coefficients, and measuring a deviation between the measured production history data and simulated production history data derived from the computational model until a match is achieved.

Abstract: An apparatus and a method for estimating interval anellipticity parameter by inversing effective anellipticity parameter in the depth domain using a least-squares method. One embodiment of interval anellipticity parameter estimator includes: 1) an interface configured to receive seismic data and borehole information; 2) a depth convertor configured to obtain a function of depth of effective anisotropy parameter based on said borehole information; 3) an inverse transformer configured to set up said function of depth of effective anisotropy parameter as a least-squares fitting problem based on said P-wave data; and 4) an iterative solver configured to use iterative methods to solve said least-squares fitting problem and to obtain an anisotropy model containing interval anellipticity parameter.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product for improving production of an oil well. For example, one disclosed embodiment includes a system that includes at least one processor and at least one memory coupled to the at least one processor and storing instructions that when executed by the at least one processor performs operations for generating a model of a wellbore in a wellbore simulator. The at least one processor further executes an algorithm that determines optimal parameters for inflow control devices (ICD) along a horizontal portion of the wellbore. The determined optimal parameters of the inflow control devices would yield a substantially uniform approach of at least one of water and gas along the horizontal portion of the wellbore.

Abstract: In some embodiments, a system, as well as a method and an article, may operate to generate map values for a plurality of parameters corresponding to respective grid blocks of a reservoir, wherein the values have been previously generated based on an initial simulation result from a model of the reservoir; to generate a sector surrogate model that includes a subset of grid blocks of the reservoir based on a criterion for identifying grid blocks that negatively affect simulation of the reservoir; to provide data inputs to execute a simulation of the reservoir using the sector surrogate model; and to generate revised data inputs, based on results of the simulation of the reservoir using the sector surrogate model, to use in a subsequent simulation using the model of the reservoir. Additional apparatus, systems, and methods are disclosed.

Abstract: A method includes creating a diffusion model for a simulation of hydrocarbon recovery from a reservoir having a plurality of fractures during injection of an injected gas into the plurality of fractures, wherein the reservoir is partitioned into a plurality of grid cells in the diffusion model. Creating the diffusion model for a grid cell of the plurality of grid cells comprises, determining a flux ratio of a convective flux to an estimated diffusive flux for the grid cell, determining whether the flux ratio is less than a threshold, and in response to determining that the flux ratio is less than the threshold, determining a full diffusive flux for the grid cell for inclusion in the diffusion model. The method also includes performing the simulation of the hydrocarbon recovery from the reservoir based on the diffusion model.

Abstract: Disclosed are systems and methods for allocating resources for executing a simulation. These include receiving a simulation for execution, calculating an initial runtime of an initial time step of the simulation, determining a total runtime of the simulation based on the initial runtime, selecting a runtime model based on the initial time step, total runtime, or a parameter of the simulation, identifying, based on the selected runtime model, an allocation of a resource providing an increase in runtime speed, allocating the identified resource, and executing the simulation using the allocated resource.

Abstract: Systems and methods for predicting drilling tool failure based on an analysis of at least one of a plot of jerk and inverse jerk for the drilling tool and a plot of drilling tool failure pattern trends data.

Abstract: Wavelet estimation may be performed in a reservoir simulation model that is constrained by seismic inversion data and well logs. A synthetic seismic trace is generated along with an estimated wavelet. The reservoir simulation model is revised based on results from model comparisons to actual data or base seismic data and is then used to perform a wavelet estimation. The estimated wavelet may then be used to plan further production at the well site environment, additional production at additional well site environments or any other production and drilling operation for any given present or future well site environment.