Abstract: The present invention is related to a computer implemented method for manipulating a numerical model of a 3D domain, said numerical model comprising geometrical entities such as layers, fractures, discontinuities, facies, etc., being identified as geometrical entities because they can be defined by its shape. The resulting data storage block is very large. The management of such large data bases or data storage block may be unaffordable as simple operations over one or more geometrical entities require the processing of the entire data base. The method provides an efficient management of the data base by a set of specific lists of indexing keys increasing the speed of access, for instance for writing and reading operations, for one or more determined geometrical entities.

Abstract: A technique is provided for modeling flow simulations at downhole reservoir conditions and rock formations after performing wellbore perforations. By utilizing these flow simulations, a user may be able to simulate and compare different scenarios, thereby facilitating a more effective, profitable, and realistic choice of perforating systems and operating conditions.

Abstract: Data collected during reservoir monitoring may include fiber optic measurements utilizing a distributed sensing system. Downhole monitoring with the distributed sensing system may generate large amounts of data. For example, the system may be capable of producing the functional equivalent of tens, hundreds, or even thousands of sensors along a length of a wellbore. Continuous monitoring of various properties, including temperature, pressure, Bragg gradient, acoustic, and strain, may create a large volume of data, possibly spanning into several gigabytes. Embodiments of the present invention provide techniques for analyzing a large volume of measurements taken in a wellbore without compromising on the integrity of data.

Abstract: A technique is provided for modeling flow simulations at downhole reservoir conditions and rock formations after performing wellbore perforations. By utilizing these flow simulations, a user may be able to simulate and compare different scenarios, thereby facilitating a more effective, profitable, and realistic choice of perforating systems and operating conditions.

Abstract: Oilfield and wellbore data may include geophone data (seismic) and airborne surveys such as microseep data, as well as fiber optic measurements collected utilizing a distributed sensing system. Continuous monitoring of various oilfield and wellbore properties, such as temperature, pressure, Bragg gradient, acoustic, and strain, and the like, may generate a large volume of data, possibly spanning into several terabytes. Embodiments of the present invention provide techniques for visualizing a large volume of such measurements taken in an oilfield or wellbore without down-sampling measurement data.

Abstract: Oilfield and wellbore data may include geophone data (seismic) and airborne surveys such as microseep data, as well as fiber optic measurements collected utilizing a distributed sensing system. Continuous monitoring of various oilfield and wellbore properties, such as temperature, pressure, Bragg gradient, acoustic, and strain, and the like, may generate a large volume of data, possibly spanning into several terabytes. Embodiments of the present invention provide techniques for visualizing a large volume of such measurements taken in an oilfield or wellbore without down-sampling measurement data.

Abstract: Oilfield and wellbore data may include geophone data (seismic) and airborne surveys such as microseep data, as well as fiber optic measurements collected utilizing a distributed sensing system. Continuous monitoring of various oilfield and wellbore properties, such as temperature, pressure, Bragg gradient, acoustic, and strain, and the like, may generate a large volume of data, possibly spanning into several terabytes. Embodiments of the present invention provide techniques for visualizing a large volume of such measurements taken in an oilfield or wellbore without down-sampling measurement data.

Abstract: Oilfield and wellbore data may include geophone data (seismic) and airborne surveys such as microseep data, as well as fiber optic measurements collected utilizing a distributed sensing system. Continuous monitoring of various oilfield and wellbore properties, such as temperature, pressure, Bragg gradient, acoustic, and strain, and the like, may generate a large volume of data, possibly spanning into several terabytes. Embodiments of the present invention provide techniques for visualizing a large volume of such measurements taken in an oilfield or wellbore without down-sampling measurement data.

Abstract: Oilfield and wellbore data may include geophone data (seismic) and airborne surveys such as microseep data, as well as fiber optic measurements collected utilizing a distributed sensing system. Continuous monitoring of various oilfield and wellbore properties, such as temperature, pressure, Bragg gradient, acoustic, and strain, and the like, may generate a large volume of data, possibly spanning into several terabytes. Embodiments of the present invention provide techniques for visualizing a large volume of such measurements taken in a oilfield or wellbore without down-sampling measurement data.

Abstract: Data collected during reservoir monitoring may include fiber optic measurements utilizing a distributed sensing system. Downhole monitoring with the distributed sensing system may generate large amounts of data. For example, the system may be capable of producing the functional equivalent of tens, hundreds, or even thousands of sensors along a length of a wellbore. Continuous monitoring of various properties, including temperature, pressure, Bragg gradient, acoustic, and strain, may create a large volume of data, possibly spanning into several gigabytes. Embodiments of the present invention provide techniques for analyzing a large volume of measurements taken in a wellbore without compromising on the integrity of data.