Abstract: A lock cylinder having a barrel and a lock housing, the barrel having a locking cam pivotally mounted therein, the locking cam including at least one recess on an outer periphery thereof, a housing recess formed on an inner wall of the lock housing, a locking member that, in a locking position, is positioned at least partly in the housing recess formed on the inner wall of the lock housing, the at least one recess on the locking cam including a first recess on the locking cam, the first recess being sized to enable the locking member to move out of the housing groove, the barrel having a key slot for receiving a key, the key including a projection for causing the locking cam to rotate to bring the first recess on the locking cam adjacent to or into alignment with the locking member such that the locking member moves out of the housing recess and into the first recess of the locking cam and barrel slot to thereby enable rotation of the barrel in the lock housing.

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.

Abstract: A lock cylinder having a barrel and a lock housing, the barrel having a locking cam pivotally mounted therein, the locking cam including at least one recess on an outer periphery thereof, a housing recess formed on an inner wall of the lock housing, a locking member that, in a locking position, is positioned at least partly in the housing recess formed on the inner wall of the lock housing, the at least one recess on the locking cam including a first recess on the locking cam, the first recess being sized to enable the locking member to move out of the housing groove, the barrel having a key slot for receiving a key, the key including a projection for causing the locking cam to rotate to bring the first recess on the locking cam adjacent to or into alignment with the locking member such that the locking member moves out of the housing recess and into the first recess of the locking cam and barrel slot to thereby enable rotation of the barrel in the lock housing.

Abstract: System and methods for predicting time-dependent rock properties are provided. Seismic data for a subsurface formation is acquired over a plurality of time intervals. A value of at least one rock property of the subsurface formation is calculated for each of the plurality of time intervals, based on the corresponding seismic data acquired for that time interval. At least one of a trend or a spatio-temporal relationship in the seismic data is determined based on the value of the at least one rock property calculated for each time interval. A value of the at least one rock property is estimated for a future time interval, based on the determination. The estimated value of the at least one rock property is used to select a location for a wellbore to be drilled within the subsurface formation. The wellbore is then drilled at the selected location.

Abstract: Systems and methods for determining non-linear petrofacies using cross-plot partitioning to define petrofacies boundaries that distinguish the petrofacies by appearance and/or composition using systematic and automated data analysis techniques.

Abstract: A system and method can be used for to calibrating time-lapse seismic volumes by cross-migration rescaling and reorientation for use in determining optimal wellbore placement or production in a subsurface environment. Certain aspects include methods for cross-migration of data sets processed using different migration techniques. Pre-processing of the data sets, optimization of rescaling and reorientation, and identification of adjustment parameters associated with minimum global error can be used to achieve a time-dependent formation data set that addresses error in all input data sets.

Abstract: At least some of the disclosed systems and methods obtain a static earth model having a three-dimensional grid with multiple cells. Further, at least some of the disclosed systems and methods determine a plurality of geobodies for the static earth model, each geobody comprising a plurality of connected cells. Further, at least some of the disclosed systems and methods compute one or more tortuosity values for at least one of the plurality of geobodies. Further, at least some of the disclosed systems and methods calibrate the static earth model based on the one or more computed tortuosity values. Further, at least some of the disclosed systems and methods use the calibrated static earth model as input to a flow simulator.

Abstract: A system and method utilizing one or more perforation filters to determine the location of perforation intervals along a well trace within a reservoir model. The filters may define the location of the perforation intervals based upon, for example, rock property, facies, fluid boundary, geobody, or dynamic fluid property.

Abstract: A system and method utilizing a modified Euler Characteristic to numerically quantify and rank connectivity of a geobody within a reservoir model based upon a range of petrophysical properties.

Abstract: A visualization module of an imaging system having a 3D geocellular model generated for illustrating rock types within a subterranean formation. The visualization module can determine that cells of the 3D geocellular model are visible to a field of view for a viewing user. For each cell determined to be visible, the visualization module can determine a rock type for the cell and that one or more faces of the cell are visible. For each face determined to be visible, the visualization module can determine an orientation of the face; determine that an image corresponds to the determined orientation and determined rock type; and apply the image to the face of the cell in the 3D geocellular model.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product for approximating multiphase flow in reservoir simulation. For example, one disclosed embodiment includes a system that includes at least one processor and memory coupled to the at least one processor, the memory storing instructions that when executed by the at least one processor performs operations that includes generating a set of pseudo-phase production relative permeability curves; receiving production rate history data; receiving simulation configuration parameters; performing flow simulation using the set of pseudo-phase production relative permeability curves; and determining an optimal matching pseudo-phase production simulation result that best matches the production rate history data in the absence of relative permeability measurements derived from the subsurface porous medium.

Abstract: A system and method are provided for creating interior seismic data between measurements of actual seismic data. The interior seismic data may be created using processes for approximating or constructing seismic data between times the actual seismic data is sampled. In some aspects, the interior seismic data may be approximated by determining a rate of change in the seismic data between at least two measurements of seismic data over time. In other aspects, the interior seismic data may be created by constructing an intermediate state of the formation between the times corresponding to at least two measurements of the seismic data based on a trend associated with the measurements. In additional aspects, a Gaussian white noise may be applied to the measurements to yield an array of equally probable predictions for the intermediate state of the property.

Abstract: A three-dimensional reservoir simulator used for automated upscaling relative permeability and capillary pressure in multi-porosity systems comprising disparate rock-types. A coarse-scale single-porosity model incorporating multi-porosity model properties may be derived from a fine-scale single-porosity model based, at least in part, on simulation of a model comprising data from one or more regions of interest. Real-world and laboratory measurements of the one or more regions of interest may be provided to the fine-scale single-porosity simulation model and the fine-scale single-porosity model may be subjected to one or more fractional flow simulation processes and one or more displacement simulation processes. The fine-scale model properties may be modified based, at least in part, on the results of the one or more fractional flow simulation processes and one or more displacement simulation processes.

Abstract: At least some of the disclosed systems and methods obtain a static earth model having multiple layers. Further, at least some of the disclosed systems and methods test a permeability associated with at least part of the static earth model. Further, at least some of the disclosed systems and methods calibrate the static earth model by adjusting a distribution or proportion of geological features in at least one of the multiple layers based on the testing. Further, at least some of the disclosed systems and methods use the calibrated static earth model to predict fluid flow in a formation.

Abstract: Systems and methods for automated upscaling of relative permeability using fractional flow in systems comprising disparate rock types after actual convergence of a production rate and an injection rate using a three-dimensional (3D) reservoir simulator.

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.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product for approximating multiphase flow reservoir production simulation for ranking multiple petro-physical realizations.

Abstract: The disclosed embodiments include a method, apparatus, and computer program product for approximating multiphase flow reservoir production simulation. For example, one disclosed embodiment includes a system that includes at least one processor and memory coupled to the at least one processor, the memory storing instructions that when executed by the at least one processor performs operations that includes generating a set of pseudo-phase production relative permeability curves; receiving production rate history data; receiving simulation configuration parameters; performing flow simulation using the set of pseudo-phase production relative permeability curves; determining an optimal matching pseudo-phase production simulation result that best matches the production rate history data; and performing relative permeability inversion using signal processing analysis of production rate history data to approximate relative permeability curve descriptions with quantified uncertainty.

Abstract: Methods and systems are presented in this disclosure for high-dimensional detection and visualization. Detection in a higher-dimensional domain of at least one of an event or one or more objects within a visualization environment can be performed by identifying at least one evolution of the event or a dynamic property of the one or more objects. The at least one evolution of the event or the one or more objects having the dynamic property can be displayed within the visualization environment. Appropriate operations can be initiated based on the at least one evolution of the event or the one or more objects.

Abstract: System and methods for defining non-linear petrofacies for a reservoir simulation model are provided. A cross-plot visualization of selected petrophysical properties from a three-dimensional (3D) geocellular grid array of petrophysical properties representing a reservoir rock formation is presented to a user via a display of a computing device. Upon receiving user input for defining a non-linear petrofacies region of the 3D geocellular grid within the presented cross-plot visualization, data points in the cross-plot visualization that are within the boundaries of the petrofacies region are identified. The identified data points are associated with the petrofacies region. Hydraulic rock properties are assigned to one or more cells of the 3D geocellular grid based on the data points associated with the petrofacies region.