Abstract: A rotatable nacelle includes an engine inlet configured to receive air and an inlet air management system (IAMS). The IAMS includes a primary inlet configured to selectively allow air to flow into a duct associated with the engine air inlet via the primary inlet and a secondary inlet configured to selectively allow air to flow into the duct associated with the engine air inlet via the secondary inlet. The secondary inlet is configured to receive an air filter.

Abstract: A method for estimation of water properties and hydrocarbon properties in a subsurface formation include acquiring a plurality of well log measurements from the subsurface formation. The water properties and the formation properties are parameterized with respect to a selected set of well log measurements. The parameterized water properties, the parameterized formation properties and the well log measurements are graphically displayed to estimate the water properties.

Abstract: A method for transforming a 2D or 3D earth volume geometry into a 1D earth volume geometry includes performing a measurement using the measurement sensor in a wellbore. A layer boundary in the 2D or 3D earth volume geometry that is nearest to the measurement sensor is identified. A vector from the measurement sensor is generated toward the nearest layer boundary. A first intersection is identified between the vector and the nearest layer boundary, and a second intersection is identified between the vector and another layer boundary. Simulated boundaries that extend through the first and second intersections and are perpendicular to the vector are generated. The 1D earth volume geometry that is bounded by the first and second intersections is identified. A property value is extracted from the 2D or 3D earth volume geometry between the first and second intersections. The property value is assigned to the 1D earth geometry.

Abstract: A method for determining a volume of a constituent(s) in a geological formation may include generating an equation of state based upon log measurements for the geological formation, with the equation of state providing a correlation between the log measurements, determining a quality factor for the equation of state, and for each of a plurality of different constituents expected to be in the formation, determining a constituent compliance factor for each of the constituents. The method may further include determining an uncertainty for each constituent compliance factor, determining a likelihood that each constituent is present in the formation based upon the quality factor, the constituent compliance factor for the constituent, and the uncertainty for the constituent compliance factor, generating a volumetric model based upon the log measurements and the determined likelihoods of the constituents in the formation, and determining the volume of the constituent(s) based upon the volumetric model.

Abstract: A method for generating a model of a formation property includes acquiring a formation property measurement. A petrophysical quantity is inverted from the formation property measurement. A model is generated based on the inverted petrophysical quantity.

Abstract: Methods, computer-readable media, and systems are disclosed for applying 1D processing in a non-1D formation. In some embodiments, a 3D model or curtain section of a subsurface earth formation may be obtained. A processing window within the 3D model or curtain that is suitable for 1D inversion processing is determined, and a local 1D model for the processing window is built. A 1D inversion is performed on the local 1D model, and inverted formation parameters are used to update the 3D model or curtain section.

Abstract: Embodiments set forth in this disclosure providing techniques for determining formation parameters, such as horizontal resistivity (Rh), vertical resistivity (Rv), and dip, in high angle and horizontal wells using non-directional resistivity measurements. For example, a method is provided that may include using an electromagnetic logging tool to acquire non-directional resistivity measurements in a wellbore of a high angle or horizontal well. The method may also include defining a processing window that corresponds to a measurement point of the electromagnetic logging tool along a well trajectory that intersects a at least one bed boundary between two layers of a subsurface formation. The method may also include defining a formation structure and defining an initial set of formation parameters for each layer in the formation structure. Furthermore, the method may include inverting the formation parameters for each layer.

Abstract: An interactive display of results obtained from the inversion of logging data is produced by obtaining and inverting the logging data using a Monte-Carlo inversion. An interactive plot having a percentile scale plotted against a location parameter is produced and a particular percentile is selected using the interactive plot. A cross-section plot for the particular percentile using the results of the Monte-Carlo inversion is produced. The particular percentile can be a curve representing a best-fit solution or a polyline representing selected solutions. Background color/shading can be displayed on the interactive plot to indicate user-defined constraints have been applied. Uncertain features can be plotted on a corresponding cross-section display using fading. Clusters of solutions that are substantially equally likely, given the measurements at a particular drill location, can be identified and plotted.

Abstract: Embodiments set forth in this disclosure providing techniques for determining formation parameters, such as horizontal resistivity (Rh), vertical resistivity (Rv), and dip, in high angle and horizontal wells using non-directional resistivity measurements. For example, a method is provided that may include using an electromagnetic logging tool to acquire non-directional resistivity measurements in a wellbore of a high angle or horizontal well. The method may also include defining a processing window that corresponds to a measurement point of the electromagnetic logging tool along a well trajectory that intersects a at least one bed boundary between two layers of a subsurface formation. The method may also include defining a formation structure and defining an initial set of formation parameters for each layer in the formation structure. Furthermore, the method may include inverting the formation parameters for each layer.

Abstract: Methods, computer-readable media, and systems are disclosed for applying 1D processing in a non-1D formation. In some embodiments, a 3D model or curtain section of a subsurface earth formation may be obtained. A processing window within the 3D model or curtain that is suitable for 1D inversion processing is determined, and a local 1D model for the processing window is built. A 1D inversion is performed on the local 1D model, and inverted formation parameters are used to update the 3D model or curtain section.

Abstract: A method for determining a volume of a constituent(s) in a geological formation may include generating an equation of state based upon log measurements for the geological formation, with the equation of state providing a correlation between the log measurements, determining a quality factor for the equation of state, and for each of a plurality of different constituents expected to be in the formation, determining a constituent compliance factor for each of the constituents. The method may further include determining an uncertainty for each constituent compliance factor, determining a likelihood that each constituent is present in the formation based upon the quality factor, the constituent compliance factor for the constituent, and the uncertainty for the constituent compliance factor, generating a volumetric model based upon the log measurements and the determined likelihoods of the constituents in the formation, and determining the volume of the constituent(s) based upon the volumetric model.

Abstract: A method for transforming a 2D or 3D earth volume geometry into a 1D earth volume geometry includes performing a measurement using the measurement sensor in a wellbore. A layer boundary in the 2D or 3D earth volume geometry that is nearest to the measurement sensor is identified. A vector from the measurement sensor is generated toward the nearest layer boundary. A first intersection is identified between the vector and the nearest layer boundary, and a second intersection is identified between the vector and another layer boundary. Simulated boundaries that extend through the first and second intersections and are perpendicular to the vector are generated. The 1D earth volume geometry that is bounded by the first and second intersections is identified. A property value is extracted from the 2D or 3D earth volume geometry between the first and second intersections. The property value is assigned to the 1D earth geometry.

Abstract: A method for generating a model of a formation property includes acquiring a formation property measurement. A petrophysical quantity is inverted from the formation property measurement. A model is generated based on the inverted petrophysical quantity.

Abstract: The present disclosure relates to a method to determine the capture cross-section of a subsurface formation at a desired depth in the formation. A database of Sigma values for known lithologies, porosities, and salinities is provided, and multiple Sigma measurements are obtained from a downhole logging tool. Within the database, Sigma values are interpolated to determine the respective depths of investigation of the multiple Sigma measurements. A monotonic function is fitted to the multiple Sigma measurements at the determined depths of investigation, and the capture cross-section of the subsurface formation at any desired depth in the formation is determined using the fitted function. Similarly, a system to determine the capture cross-section of a subsurface formation at a desired depth in the formation and/or a depth of invasion of drilling fluids is also disclosed.

Abstract: An interactive display of results obtained from the inversion of logging data is produced by obtaining and inverting the logging data using a Monte-Carlo inversion. An interactive plot having a percentile scale plotted against a location parameter is produced and a particular percentile is selected using the interactive plot. A cross-section plot for the particular percentile using the results of the Monte-Carlo inversion is produced. The particular percentile can be a curve representing a best-fit solution or a polyline representing selected solutions. Background color/shading can be displayed on the interactive plot to indicate user-defined constraints have been applied. Uncertain features can be plotted on a corresponding cross-section display using fading. Clusters of solutions that are substantially equally likely, given the measurements at a particular drill location, can be identified and plotted.

Abstract: A logging tool having a plurality of different sensor types having close spacings mounted on an articulated or extendible pad, a sleeve, a mandrel, a stabilizer, or some combination of those is provided and used to make measurements in a wellbore in a single logging run. Those measurements are used to create images of the wellbore and the images are used to deduce the local geology, optimize well placement, perform geomechanical investigation, optimize drilling operations, and perform formation evaluation. The logging tool includes a processor capable of making those measurements, creating those images, performing those operations, and making those determinations. The plurality of different sensors may be one or more resistivity sensors, dielectric sensors, acoustic sensors, ultrasonic sensors, caliper sensors, nuclear magnetic resonance sensors, natural spectral gamma ray sensors, spectroscopic sensors, cross-section capture sensors, and nuclear sensors, and they may be “plug-and-play” sensors.

Abstract: The invention relates to methods and apparatus for determining a downhole parameter in an underbalanced drilling environment which include: selectively activating a first fluid flowing from the formation through a wellbore while under balanced drilled; detecting the activated first fluid, and determining a depth at which said fluid enters the wellbore.

Abstract: The invention relates to methods and apparatus for determining a downhole parameter in an underbalanced drilling environment which include: selectively activating a first fluid flowing from the formation through a wellbore while under balanced drilled; detecting the activated first fluid, and determining a depth at which said fluid enters the wellbore.

Abstract: A method is disclosed for modeling a first reservoir while drilling a wellbore into a corresponding second reservoir, the first reservoir having a plurality of stations, comprising: determining a plurality of values of net present value corresponding, respectively, to the plurality of stations of the first reservoir; and drilling the wellbore into the corresponding second reservoir in accordance with the plurality of values of net present value.

Abstract: The present disclosure relates to a method to determine the capture cross-section of a subsurface formation at a desired depth in the formation. A database of Sigma values for known lithologies, porosities, and salinities is provided, and multiple Sigma measurements are obtained from a downhole logging tool. Within the database, Sigma values are interpolated to determine the respective depths of investigation of the multiple Sigma measurements. A monotonic function is fitted to the multiple Sigma measurements at the determined depths of investigation, and the capture cross-section of the subsurface formation at any desired depth in the formation is determined using the fitted function. Similarly, a system to determine the capture cross-section of a subsurface formation at a desired depth in the formation and/or a depth of invasion of drilling fluids is also disclosed.