Abstract: A method for formation properties prediction in near-real time may include obtaining lab measurements of existing drill cuttings at a plurality of depths of a first well. The method may include obtaining historical drilling surface data at the plurality of depths from a plurality of wells. The method may include obtaining real-time digital photos and real-time drilling surface data of new drill cuttings at a new depth of a new well. The method may include generating, using a prediction model, predicted formation properties of the new drill cuttings based on the real-time digital photos, the real-time drilling surface data, and the new depth. The method may include predicting, using a near-real-time model and the predicted formation properties, near-real-time formation properties in the new well, wherein the prediction model comprises a historical model that employs a machine-learning algorithm.

Abstract: A method of determining the depth of a sidewall core sample taken from a borehole relative to a reference log of the borehole. The method includes obtaining a reference log recorded on a reference log depth scale and a borehole image log recorded on a borehole image log depth scale of a portion of the borehole from which the sidewall core sample has been taken. The method further includes generating a calibrated borehole image log from the borehole image log and the reference log and identifying a candidate sidewall core image artifact in the calibrated borehole image log. The method also includes assigning a confidence value for the candidate sidewall core image artifact based on a characteristic of the candidate sidewall core image artifact, and determining, using the confidence value, a probability that the sidewall core sample was collected at a certain depth on the reference log depth scale.

Abstract: Methods and systems for calibrating a subsidence map are disclosed. The method includes selecting a stratigraphic model that represents a geological formation and defining the subsidence map with a first set of variable values. The method further includes obtaining target outputs measured from the geological formation. The method still further includes determining first model outputs from the stratigraphic model by inputting the subsidence map with the first set of variable values into the stratigraphic model and determining a first residual between the target outputs and the first model outputs using an objective function.

Abstract: A system and method automatically orient geological core samples. The system comprises a camera, a core analyzer module, and a core sample rotation apparatus. The camera is configured to capture a reference image of a cross-section of a reference core sample from a well and to capture a sample image of a cross-section of the to-be-oriented core sample from the well. The core analyzer module comprises code executable in a hardware processor to process the sample image to substantially match the reference image, and to determine an orientation angle of the match. The core sample rotation apparatus is configured to orient the to-be-oriented core sample by the orientation angle. A method comprises steps performed during operation of the system.

Abstract: A method of determining the depth of a sidewall core sample taken from a borehole relative to a reference log of the borehole. The method includes obtaining a reference log recorded on a reference log depth scale and a borehole image log recorded on a borehole image log depth scale of a portion of the borehole from which the sidewall core sample has been taken. The method further includes generating a calibrated borehole image log from the borehole image log and the reference log and identifying a candidate sidewall core image artifact in the calibrated borehole image log. The method also includes assigning a confidence value for the candidate sidewall core image artifact based on a characteristic of the candidate sidewall core image artifact, and determining, using the confidence value, a probability that the sidewall core sample was collected at a certain depth on the reference log depth scale.

Abstract: Provided are systems and methods for shifting core data to account for flaws that include segmenting core data into multiple contiguous core segments defined by breaking points and iteratively assessing and shifting the segments in sequence (from the deepest segment to the shallowest segment) to align the core data of the contiguous core segments with corresponding segments of log data. For each shift of an assessed segment by a given distance the shallower segments of core data are shifted by the given distance. The breaking points used to define contiguous core segments are identified based on image processing of an image of the core, including identification and comparison of Haralick textual feature parameters across different portions of the core image.

Abstract: The invention is a method, having applications for the development of reservoirs, for predicting the production of an underground reservoir, comprising generating and updating a parameterized geologic model from production data and seismic data and in particular 4D seismic data which may be used in development of oil reservoirs. According to the method, production data are simulated from the geologic model and a flow simulator, and a petro-elastic depth model is deduced therefrom. A depth/time conversion model is then defined, by means of which the petro-elastic model is converted into time. The model is adjusted by correcting the lag induced by the depth/time conversion and by recalibrating the model. The geologic model is optimized by comparing, through an objective function, the real measurements with the simulation responses (production responses and seismic attributes in time) by updating in particular the depth/time conversion model.

Abstract: A method having an application to production problems in reservoir engineering for quickly forming a stochastic model representative of the distribution of a physical quantity in a porous heterogeneous medium, which is calibrated in relation to dynamic data, by suitable selection of geostatistical realizations to be combined linearly. An iterative gradual deformation process is used, wherein an initial geostatistical realization (y) of the medium and a number (N?1)(N>1) of other realizations (zi)i=1, . . . ,(N?1), which are independent of initial realization (y), are linearly combined at each iteration, by applying constraints to the linear combination coefficients of realizations (y) and (zi)i=1, . . . ,(N?1), and an objective function (J) measuring the difference between a set of simulated data deduced from said combination by means of a simulator and said dynamic data is minimized.

Abstract: The invention relates to a method allowing prediction of the production of an underground reservoirs, such as development of oil reservoirs, comprising generating and updating a parameterized geologic model from production data and seismic data, in particular 4D seismic data. The production data are simulated from the geologic model and a flow simulator, and a petro-elastic model in depth is deduced therefrom. A depth/time conversion model is then defined, by means of which the petro-elastic model is converted into time. The model is adjusted by correcting the lag induced by the depth/time conversion and by recalibrating the model. The geologic model is optimized by comparing, through an objective function, the real measurements with the simulation responses (production responses and seismic attributes in time) by updating in particular the depth/time conversion model.

Abstract: A method having an application to production problems in reservoir engineering for quickly forming a stochastic model representative of the distribution of a physical quantity in a porous heterogeneous medium, which is calibrated in relation to dynamic data, by suitable selection of geostatistical realizations to be combined linearly. An iterative gradual deformation process is used, wherein an initial geostatistical realization (y) of the medium and a number (N?1)(N>1) of other realizations (zi)i=1, . . . ,(N?1), which are independent of initial realization (y), are linearly combined at each iteration, by applying constraints to the linear combination coefficients of realizations (y) and (zi)i=1, . . . ,(N?1), and an objective function (J) measuring the difference between a set of simulated data deduced from said combination by means of a simulator and said dynamic data is minimized.

Abstract: The invention is a method for direct updating, by dynamic production data, of a fine geologic model representative of the distribution, in a reservoir, of a physical quantity characteristic of the subsoil structure. The method couples inversion and upscaling techniques allowing optimization of petrophysical parameters of a rougher simulation model resulting from the fine geologic model. Direct parameterization of the fine geologic model is performed followed by upscaling only as a means of obtaining rapidly an approximation of simulation results and of derivatives thereof in relation to the parameterization of the fine geologic model. The model has applications for determination of a development scheme such as optimizing the production of a hydrocarbon reservoir.

Abstract: Method intended for direct updating, by dynamic production data, of a fine geologic model representative of the distribution, in a reservoir, of a physical quantity characteristic of the subsoil structure.