Patent application number | Description | Published |
20100027686 | IMAGE COMPRESSION AND DECOMPRESSION - Clusters of pixels are defined for use in image compression and decompression. The image information used to define the clusters may include pixel values at predetermined positions relative to a pixel or related motion vectors, gradients, texture etc. During compression of images the image information relative to pixels is examined to determine the cluster to which it belongs. Thus pixels can be classified according to the cluster for their image information. In an embodiment the definitions of the clusters are selected dynamically, dependent on image content. For each cluster a control parameter set is computed for a post-processing operation, such as filter coefficients for filtering or statistical data for locally generating texture. The control parameter set is selected dependent on the image content so that, when the post-processing operation is applied to the image after decompression it will improve image quality for the pixels that are classified as belonging to the cluster. The compressed image and the control parameter sets are transmitted to a decompression apparatus. Upon decompression, the image information that represents the decompressed image is examined to classify pixels according to the clusters and the different control parameter sets for the selected clusters are used to control post-processing at the locations of the pixels. | 02-04-2010 |
20100074328 | METHOD AND SYSTEM FOR ENCODING AN IMAGE SIGNAL, ENCODED IMAGE SIGNAL, METHOD AND SYSTEM FOR DECODING AN IMAGE SIGNAL - An image signal is encoded to reduce artifacts. In an original image frame (F) one or more gradual transition areas (R) are identified, in a decoded frame (F) corresponding one or more gradual transition areas (R) are identified, functional parameters describing the data content of the one or more gradual transition areas of the original image frame are established and position data (P) for the positions of the one or more corresponding areas (R′) in the decoded frame (F′) are established. Replacing the content of the areas R′ in the decoded frame with the reconstructed content of the areas R in the original frame improves the quality of the decoded frame. | 03-25-2010 |
20110221963 | DISPLAY SYSTEM, CONTROL UNIT, METHOD, AND COMPUTER PROGRAM PRODUCT FOR PROVIDING AMBIENT LIGHT WITH 3D SENSATION - A display system having 3D ambient light functionality is provided. The system comprises at least light source for providing ambient light having color and/or intensity dependent on the image content. The system comprises a control unit configured to control the color and intensity of light emitted from each light source to produce a 3D-viewing sensation, at least partly based on depth information. | 09-15-2011 |
20130041259 | PROPERTY DETERMINING APPARATUS FOR DETERMINING A PROPERTY OF AN OBJECT - A monitoring apparatus for monitoring an ablation procedure applied to an object comprises an ultrasound signal providing unit for providing an ultrasound signal. The ultrasound signal is produced by sending ultrasound pulses out to the object, by subsequently receiving dynamic echo series after the ultrasound pulses have been reflected by the object, and finally by generating the ultrasound signal depending on the received dynamic echo series, whereby ultrasound scattering properties of the object are determined that represent blood perfusion. The monitoring apparatus further comprises an ablation depth determination unit for determining an ablation depth from the provided ultrasound signal. | 02-14-2013 |
20130230226 | APPARATUS FOR BEING USED FOR DETECTING A PROPERTY OF AN OBJECT - The invention relates to an apparatus for being used for detecting a property of an object. An ultrasound signal providing unit ( | 09-05-2013 |
20140079330 | IMAGE COMPRESSION AND DECOMPRESSION - Clusters of pixels are defined for image compression and decompression. The image information used to define the clusters may include pixel values at predetermined positions relative to a pixel or related motion vectors, gradients, texture etc. During compression of images, image information relative to pixels is examined to determine the cluster to which it belongs. Thus pixels can be classified according to the cluster for their image information. In an embodiment the definitions of the clusters are selected dynamically, dependent on image content. For each cluster a control parameter set is computed for a post-processing operation, such as filter coefficients for filtering or statistical data for locally generating texture. The control parameter set is selected dependent on the image content so that, when the post-processing operation is applied to the image after decompression it will improve image quality for the pixels that are classified as belonging to the cluster. | 03-20-2014 |
20150038842 | IMAGING SYSTEM FOR IMAGING A PERIODICALLY MOVING OBJECT - The invention relates to an imaging system for imaging a periodically moving object. An assigning unit ( | 02-05-2015 |
20150374343 | ULTRASOUND IMAGING SYSTEM AND METHOD - The present invention relates to an ultrasound imaging system ( | 12-31-2015 |
Patent application number | Description | Published |
20120232799 | METHODS AND APPARATUS FOR CHARACTERIZATION OF PETROLEUM FLUID EMPLOYING ANALYSIS OF HIGH MOLECULAR WEIGHT COMPONENTS - A methodology that performs downhole fluid analysis of fluid properties of a reservoir and characterizes the reservoir based upon such downhole fluid analysis. The methodology acquires at least one fluid sample at a respective measurement station and performs downhole fluid analysis to measure properties of the fluid sample, including concentration of a plurality of high molecular weight components. For each of a plurality of type classes corresponding to different subsets of a predetermined set of high molecular weight components, a model is used to predict the concentration of the components of the given type class for the plurality of measurement stations. The predicted concentrations of the high molecular weight components for the plurality of type classes are then compared with corresponding concentrations measured by downhole fluid analysis for the plurality of measurement stations to identify the best matching type class. The results of the comparison are used for reservoir analysis, | 09-13-2012 |
20120232859 | METHOD ANS SYSTEMS FOR RESERVOIR MODELING, EVALUATION AND SIMULATION - Fluid property modeling that employs a model that characterizes asphaltene concentration gradients is integrated into a reservoir modeling and simulation framework to allow for reservoir compartmentalization (the presence or absence of flow barrier in the reservoir) to be assessed more quickly and easily. Additionally, automated integration of the fluid property modeling into the reservoir modeling and simulation framework allows the compositional gradients produced by the fluid property modeler (particularly asphaltene concentration gradients) to be combined with other data, such as geologic data and other petrophysical data, which allows for more accurate assessment of reservoir compartmentalization. | 09-13-2012 |
20130085674 | REAL-TIME COMPOSITIONAL ANALYSIS OF HYDROCARBON BASED FLUID SAMPLES - Accurate, real-time formation fluids analysis can be accomplished using the systems and techniques described herein. A fluid analyzer includes a first mode of analysis, such as an optical analyzer, configured to determine a physical (optical) property of a fluid sample. The fluid analyzer also includes another mode of analysis, such as a composition analyzer, such as a gas chromatographer, configured to determine an elemental composition of the fluid sample. A data processor is configured to determine a quantity, such as a weight percentage, of a target component of the fluid sample in response results obtained from the first and second modes of analysis. Beneficially, the results are obtained at least in near real-time, allowing for interim results, such as results from the first analyzer to be used for one or more of tuning the compositional analyzer and for implementing quality control. | 04-04-2013 |
Patent application number | Description | Published |
20150047835 | Downhole Fluid Analysis Method And Apparatus For Determining Hydrogen Indexes - The present disclosure relates to determining hydrogen indexes of downhole fluids using fluid composition data. In certain embodiments, the type of the fluid, such as gas, water, or oil, may be determined downhole and used to select a method for determining the hydrogen index of the fluid. The selected method may then be employed while the tool is downhole to calculate the hydrogen index of the fluid. | 02-19-2015 |
20150136962 | Assessing Reservoir Connectivity In Hydrocarbon Reservoirs - A method is disclosed for assessing connectivity between sections in a hydrocarbon reservoir. Samples of hydrocarbons are collected over different depths in at least one wellbore. Fluorescence intensity determines the actual heavy end concentrations of hydrocarbons for the corresponding COLLECT GAS CONDENSATE different depths. Estimated heavy end concentrations of hydrocarbons for corresponding different depths are determined and the actual heavy end concentrations of hydrocarbons are compared with the estimated heavy end concentrations to assess connectivity between sections of the hydrocarbon reservoir. | 05-21-2015 |
20150159484 | Downhole Fluid Analysis Methods For Determining Viscosity - The present disclosure relates to methods and apparatus for determining a viscosity-pressure profile of downhole fluid by measuring the viscosity at several different pressures during a sampling operation. According to certain embodiments, the viscosity may be measured at different times during a sampling operation and used to generate the viscosity-pressure profile. For example, the viscosity may be measured at the beginning of pumping, during filling of a sample chamber, during a pressure-build up period, and while retracting the probe. The measured viscosities may then be employed to determine a profile that represents the change in viscosity that occurs with pressure. | 06-11-2015 |
20150185360 | Asphaltene Gradient Modeling Methods - The present disclosure relates to methods and systems for developing an equation of state model for petroleum fluids. In one embodiment, formation fluid from a plurality of depths within a wellbore may be analyzed to determine a change in a gas oil ratio with respect to depth. The change in the gas oil ratio may be employed to determine a ratio of solubility and entropy terms to a gravity term. The resulting ratio can be used to develop the equation of state model. | 07-02-2015 |
20150226063 | Fluid Analysis Methods and Apparatus for Determining Gas-Oil Ratio - The present disclosure relates to methods and apparatus for determining a gas-oil ratio based on downhole fluid analysis measurements and calibrated gas-oil ratio parameters. According to certain embodiments, the parameters for calculating the gas-oil ratio may be calibrated using historical data from the reservoir. For example, previously determined gas-oil ratios may be employed to calibrate the parameters to the reservoir. The calibrated parameters may then be employed during sampling operations to determine the gas-oil ratio. | 08-13-2015 |
20150247941 | INTEGRATION OF SEISMIC DATA WITH DOWNHOLE FLUID ANALYSIS TO PREDICT THE LOCATION OF HEAVY HYDROCARBON - Various implementations directed to the integration of seismic data with downhole fluid analysis to predict the location of heavy hydrocarbon are provided. In one implementation, a method may include receiving seismic data for a hydrocarbon reservoir of interest. The method may also include identifying geological features associated with a secondary gas charge from the seismic data. The method may further include determining the proximity of the geological features to the hydrocarbon reservoir of interest. The method may additionally include receiving preliminary downhole fluid analysis (DFA) data from formations at or near the hydrocarbon reservoir of interest. The method may further include analyzing the preliminary DFA data to determine the equilibrium state of the hydrocarbon reservoir and to confirm the secondary gas charge in the hydrocarbon reservoir. The method may also include determining whether to perform one or more additional DFA's. | 09-03-2015 |
20150247942 | ASSESSING RISKS OF COMPARTMENTALIZATION - Various implementations described herein are directed to a method for assessing risks of compartmentalization. In one implementation, the method may include receiving seismic data for a formation of interest; identifying areas in the formation having a dip angle greater than about | 09-03-2015 |
20150308264 | Downhole Real-Time Filtrate Contamination Monitoring - A method includes identifying linearly behaving data within obtained data associated with fluid obtained from a subterranean formation. Shrinkage factor is determined based on the linearly behaving data. A function relating GOR data of the obtained fluid with the determined shrinkage factor is determined. A first linear relationship between optical density (OD) data of the obtained fluid and the function is determined. A second linear relationship between density data of the obtained fluid and the function is determined. An oil-based mud (OBM) filtrate contamination property of OBM filtrate within the obtained fluid based on the first linear relationship is determined. A native formation property of native formation fluid within the obtained fluid based on the second linear relationship is determined. A volume fraction of OBM filtrate contamination within the obtained fluid based on the OBM filtrate contamination property and the native formation property is estimated. | 10-29-2015 |
20160047208 | Tar Mat Formation Prediction in Late-Charge Reservoirs - A downhole tool, surface equipment, and/or remote equipment are utilized to obtain data associated with a subterranean hydrocarbon reservoir, fluid contained therein, and/or fluid obtained therefrom. At least one condition indicating that a density inversion exists in the fluid contained in the reservoir is identified from the data. Molecular sizes of fluid components contained within the reservoir are estimated from the data. A model of the density inversion is generated based on the data and molecular sizes. The density inversion model is utilized to estimate the density inversion amount and depth and time elapsed since the density inversion began to form within the reservoir. A model of a gravity-induced current of the density inversion is generated based on the data and the density inversion amount, depth, and elapsed time. | 02-18-2016 |
20160090836 | Flow Regime Identification with Filtrate Contamination Monitoring - A method includes operating a downhole acquisition tool in a wellbore in a geological formation. The wellbore or the geological formation, or both contains a fluid that includes a native reservoir fluid of the geological formation and a contaminant. The method also includes receiving a portion of the fluid into the downhole acquisition tool, measuring a fluid property of the portion of the fluid using the downhole acquisition tool, and using the processor to estimate a fluid property of the native reservoir fluid based on the measured fluid property of the portion of the fluid and a regression model that may predict an asymptote of a growth curve. The asymptote corresponds to the estimated fluid property of the native formation fluid, and the regression model includes a geometric fitting model other than a power-law model. | 03-31-2016 |
20160091389 | Systems and Methods for Sample Characterization - The present disclosure relates to systems and methods for determining an integrity of a sample chamber. In certain embodiments, formation fluid is collected from a subterranean formation within a sample chamber disposed in a downhole tool, the downhole tool is withdrawn from a wellbore, an estimated surface pressure of the collected formation fluid is determined, the estimated surface pressure of the collected formation fluid is compared with an actual surface pressure of the sample chamber, and the integrity of the sample chamber is determined based on the comparison of the estimated surface pressure and the actual surface pressure. | 03-31-2016 |
20160123953 | Evaluating Reservoir Oil Biodegradation - Upper and lower asphaltene weight fractions of fluid proximate ends of an oil column are obtained based on measured OD. Upper and lower maltene partial densities are obtained based on the asphaltene weight fractions. A maltene partial density distribution is obtained utilizing the maltene partial densities and a predetermined diffusion model. An asphaltene partial density distribution is obtained based on the maltene partial density distribution and an estimated mass density gradient. An asphaltene weight percentage is obtained based on the asphaltene partial density distribution and the mass density gradient. The asphaltene weight percentage distribution is converted to an OD distribution utilizing a predetermined correlation. An optimization then reduces differences between the OD distribution and the measured OD data to within a predetermined range to refine a biodegradation time of the predetermined diffusion model. A viscosity distribution may be obtained based on the optimized OD distribution. | 05-05-2016 |
20160130940 | Systems and Methods For Formation Fluid Sampling - Embodiments of the disclosure can include systems and methods for formation fluid sampling. In one embodiment, a method can include monitoring a relationship between a first characteristic of a formation fluid extracted from a formation and a second characteristic of the formation fluid extracted from the formation, determining, based at least in part on the monitoring, that a linear trend is exhibited by the relationship between the first characteristic of the formation fluid extracted from the formation and the second characteristic of the formation fluid extracted from the formation, and determining a reservoir fluid breakthrough based at least in part on the identification of the linear trend, wherein the reservoir fluid breakthrough is indicative of virgin reservoir fluid entering a sampling tool. | 05-12-2016 |
20160131630 | Methods and Systems for Correction of Oil-Based Mud Filtrate Contamination on Saturation Pressure - Embodiments of the disclosure can include systems, methods, and devices for determining saturation pressure of an uncontaminated fluid. Downhole saturation pressure measurements and downhole OBM filtrate contamination of a contaminated fluid may be obtained and a relationship may be determined between the saturation pressure measurements and OBM filtrate contamination. The relationship may be extrapolated to zero OBM filtrate contamination to determine the saturation pressure of the uncontaminated fluid. In some embodiments, OBM filtrate contamination may be determined from downhole saturation pressure measurements during pumpout of a fluid. | 05-12-2016 |