Abstract: Well core data descriptions are received as input digital data for computer lithofacies modeling. Digital templates are established for carbonate and clastic core description based on reservoir rock formation analysis. Description criteria of the template for carbonate rock can include texture, mineral composition, grain size, and pore type. For clastic rock, the criteria in the template can include grain size, sedimentary structure, lithology, and visual porosity. The data and observations regarding these criteria are entered into a computer 3D geological modeling system directly. Wireline log data are integrated to calibrate with well core description to derive lithofacies. The lithofacies are exported in digital format to be entered into the 3D geological modeling system. A geologically realistic model of the reservoir can be established.

Abstract: Methods, systems, and apparatus, including computer programs encoded on a computer storage medium, to identify geobodies for exploration and production activities.

Abstract: A dataset is generated in a database using standardized paleo-fossil and sedimentary information. Analytical operations are executed on the generated dataset. A reservoir zone thickness of a stratigraphic zone is determined based on a result of the analytical operations, where the analytical operations determine a starting occurrence and an ending occurrence of a one or more particular paleo-fossils, and where the starting occurrence and ending occurrence is used to define boundaries of the stratigraphic zone and to determine the reservoir zone thickness. A fault and fracture analysis is performed based on a result of the analytical operations. In real-time, at least one action of a hydrocarbon recovery drill is controlled, where control of the at least one action is based upon geological datum and the determined reservoir zone thickness or predictions based on the result of the fault and fracture analysis.

Abstract: The present disclosure describes methods and systems, including computer-implemented methods, computer-program products, and computer systems for integration of physical reservoir rock interpretation data into reservoir formation modeling. At least one digital photograph of a rock outcrop is generated using a mobile device and the contact and boundary features associated with the at least one digital photograph are interpreted using the mobile device. A reservoir modulation trend is generated from the interpretation of the at least one digital photograph and transmitted to a three-dimensional reservoir interpretation system. A three-dimensional lithofacies model is generated using the generated reservoir modulation trend.

Abstract: Methods, systems, and apparatus, including computer programs encoded on a computer storage medium, to identify geobodies for exploration and production activities.

Abstract: A dataset is generated in a database using standardized paleo-fossil and sedimentary information. Analytical operations are executed on the generated dataset. A reservoir zone thickness of a stratigraphic zone is determined based on a result of the analytical operations, where the analytical operations determine a starting occurrence and an ending occurrence of a one or more particular paleo-fossils, and where the starting occurrence and ending occurrence is used to define boundaries of the stratigraphic zone and to determine the reservoir zone thickness. A fault and fracture analysis is performed based on a result of the analytical operations. In real-time, at least one action of a hydrocarbon recovery drill is controlled, where control of the at least one action is based upon geological datum and the determined reservoir zone thickness or predictions based on the result of the fault and fracture analysis.

Abstract: The present disclosure describes computer-implemented methods, computer-program products, and computer systems, for providing parameters for successful automated fault patch extraction. Attributes are selected for annotating images generated from, and for interpretation of, seismic amplitude volume. Images are generated from layers of a seismic cube, each generated using a different attribute of the plural attributes. The plural images are blended using customized palettes and initial parameters to create a blended image illuminating discontinuities in the layers. Optimal parameters are iteratively determined for automatic derivation of fault discontinuities on an interpreter-selected edge-enhanced sub-volume. The iterations are controlled and terminated based on interpreter inputs. The optimal extraction parameters are applied to an entire edge-enhanced volume. Important extracted fault discontinuities are isolated using commercial filtering tools.

Abstract: The present disclosure describes computer-implemented methods, computer-program products, and computer systems, for providing parameters for successful automated fault patch extraction. Attributes are selected for annotating images generated from, and for interpretation of, seismic amplitude volume. Images are generated from layers of a seismic cube, each generated using a different attribute of the plural attributes. The plural images are blended using customized palettes and initial parameters to create a blended image illuminating discontinuities in the layers. Optimal parameters are iteratively determined for automatic derivation of fault discontinuities on an interpreter-selected edge-enhanced sub-volume. The iterations are controlled and terminated based on interpreter inputs. The optimal extraction parameters are applied to an entire edge-enhanced volume. Important extracted fault discontinuities are isolated using commercial filtering tools.

Abstract: The present disclosure describes computer-implemented methods, computer-program products, and computer systems, for providing parameters for successful automated fault patch extraction. Attributes are selected for annotating images generated from, and for interpretation of, seismic amplitude volume. Images are generated from layers of a seismic cube, each generated using a different attribute of the plural attributes. The plural images are blended using customized palettes and initial parameters to create a blended image illuminating discontinuities in the layers. Optimal parameters are iteratively determined for automatic derivation of fault discontinuities on an interpreter-selected edge-enhanced sub-volume. The iterations are controlled and terminated based on interpreter inputs. The optimal extraction parameters are applied to an entire edge-enhanced volume. Important extracted fault discontinuities are isolated using commercial filtering tools.

Abstract: A roadmap for a field development strategy for optimal recovery is provided in a high quality 3D geological model. This geological model combines geological attributes, pore and rock properties for an optimum 3D representation of the reservoir thousands of feet beneath the surface. The model is based on the pertinent geological facies, derived from well core description and detailed studies of rock, as well as fluid and pore properties (Full Pore System) obtained from laboratory analyses of core material and well log data. These data differentiate various important pore throat and pore body regions and relationships, i.e., macroporosity and microporosity. Understanding hydrocarbon volumes in the various pore type groups and then establishing proper recovery techniques through focused laboratory studies yields a field development strategy that can significantly increase hydrocarbon recovery from a reservoir.

Abstract: The present disclosure describes methods and systems, including computer-implemented methods, computer-program products, and computer systems, for providing 360-degree well core sample photo image integration, calibration, and interpretation for modeling of reservoir formations and lithofacies distribution. One computer-implemented method includes receiving a 360-degree well core sample photo image, geospatially anchoring, by a computer, the received 360-degree well core sample photo image, decomposing, by a computer, the geospatially-anchored 360-degree well core sample photo image into a color numerical array, transforming, by a computer, the color numerical array into a formation image log, calibrating, by a computer, the formation image log for consistency with additionally available data, and generating, by a computer, 3D lithofacies interpretation and prediction data using the formation image log.

Abstract: The present disclosure describes methods and systems, including computer-implemented methods, computer-program products, and computer systems for integration of physical reservoir rock interpretation data into reservoir formation modeling. At least one digital photograph of a rock outcrop is generated using a mobile device and the contact and boundary features associated with the at least one digital photograph are interpreted using the mobile device. A reservoir modulation trend is generated from the interpretation of the at least one digital photograph and transmitted to a three-dimensional reservoir interpretation system. A three-dimensional lithofacies model is generated using the generated reservoir modulation trend.

Abstract: The present disclosure describes methods and systems, including computer-implemented methods, computer-program products, and computer systems, for providing 360-degree well core sample photo image integration, calibration, and interpretation for modeling of reservoir formations and lithofacies distribution. One computer-implemented method includes receiving a 360-degree well core sample photo image, geospatially anchoring, by a computer, the received 360-degree well core sample photo image, decomposing, by a computer, the geospatially-anchored 360-degree well core sample photo image into a color numerical array, transforming, by a computer, the color numerical array into a formation image log, calibrating, by a computer, the formation image log for consistency with additionally available data, and generating, by a computer, 3D lithofacies interpretation and prediction data using the formation image log.

Abstract: Reservoir properties or attributes such as water saturation, porosity and permeability are determined directly at each cell of a three dimensional grid of a subsurface hydrocarbon reservoir. Input parameters based on original data from petrophysical measurements and other attributes of the reservoir and its subsurface features are generated over a range of uncertainties for the individual cells. The predicted input parameters for the individual cells are provided as processing inputs for petrophysical algorithms. The input parameters at different measures of possible uncertainties for the cells of the reservoir are processed using cluster computers to determine on a cell-by-cell basis a number of possible scenarios or results for the reservoir attributes of interest.

Abstract: A roadmap for a field development strategy for optimal recovery is provided in a high quality 3D geological model. This geological model combines geological attributes, pore and rock properties for an optimum 3D representation of the reservoir thousands feet beneath the surface. The model is based on the pertinent geological facies, derived from well core description and detailed studies of rock, as well as fluid and pore properties (Full Pore System) obtained from laboratory analyses of core material and well log data. These data differentiate various important pore throat and pore body regions and relationships, i.e., macroporosity and microporosity. Understanding hydrocarbon volumes in the various pore type groups and then establishing proper recovery techniques through focused laboratory studies yields a field development strategy that can significantly increase hydrocarbon recovery from a reservoir.

Abstract: Well core data descriptions are received as input digital data for computer lithofacies modeling. Digital templates are established for carbonate and clastic core description based on reservoir rock formation analysis. Description criteria of the template for carbonate rock can include texture, mineral composition, grain size, and pore type. For clastic rock, the criteria in the template can include grain size, sedimentary structure, lithology, and visual porosity. The data and observations regarding these criteria are entered into a computer 3D geological modeling system directly. Wireline log data are integrated to calibrate with well core description to derive lithofacies. The lithofacies are exported in digital format to be entered into the 3D geological modeling system. A geologically realistic model of the reservoir can be established.

Abstract: Reservoir properties or attributes such as water saturation, porosity and permeability are determined directly at each cell of a three dimensional grid of a subsurface hydrocarbon reservoir. Input parameters based on original data from petrophysical measurements and other attributes of the reservoir and its subsurface features are generated over a range of uncertainties for the individual cells. The predicted input parameters for the individual cells are provided as processing inputs for petrophysical algorithms. The input parameters at different measures of possible uncertainties for the cells of the reservoir are processed using cluster computers to determine on a cell-by-cell basis a number of possible scenarios or results for the reservoir attributes of interest.

Abstract: An earth model is formed in real time during drilling of a well by incorporating up-to-the-minute knowledge derived from geology, seismic, drilling, and engineering data. The process of forming the model utilizes Logging-While-Drilling (LWD) or Measuring-While-Drilling (MWD) data directly from the drilling rig as the well is drilled. The LWD or MWD data is sent to visualization centers and compared with other data such as existing geological models, the proposed well plan and present interpretation of the subsurface stratigraphy. The results of the comparison enable experts to analyze anomalous results and update the geological model within minutes of penetration of a formation during drilling. Well drilling efficiency is improved, and an “on-the-spot” road map is provided for maximal reservoir contact and pinpoint accuracy.