Abstract: A method for predicting oil flow rates is provided. The method includes accessing historical data from a plurality of databases, accessing historical perforation data and historical reservoir properties data from a simulation model, and determining fluid flow values and rock quality index values associated with perforated intervals of the plurality of wells. The method further includes corresponding the fluid flow values and rock quality values to the well production data, training, using the plurality of input values, a machine learning model for predicting oil flow values at perforated intervals of a plurality of target wells, predicting, using the trained machine learning model, the oil flow values at the perforated intervals of the plurality of target wells, and generating a synthetic production log that includes the predicted oil flow values at the perforated intervals of the plurality of target wells.

Abstract: The determination of subsurface three-phase saturation (that is, oil, water, and gas saturation) across perforations and open completions of production wells using production rates and pressure measurements. A process may use the surface production rates of oil, water, and gas and measured pressures to determine well fractional flows. The subsurface three-phase saturation may be determined using the cell fractional flows calculated from the well fractional flows. Computer-readable media and systems for determining subsurface three-phase saturation are also provided.

Abstract: The determination of subsurface three-phase saturation (that is, oil, water, and gas saturation) across perforations and open completions of production wells using production rates and pressure measurements. A process may use the surface production rates of oil, water, and gas and measured pressures to determine well fractional flows. The subsurface three-phase saturation may be determined using the cell fractional flows calculated from the well fractional flows. Computer-readable media and systems for determining subsurface three-phase saturation are also provided.

Abstract: A method for determining a plurality of saturation values is provided. The method accessing, by a computing device, data describing a plurality of fluid volume values associated with a reservoir, the plurality of fluid volume values include a plurality of cumulative water volume values and a plurality of cumulative hydrocarbon values, utilizing, by the computing device, the data describing the plurality of fluid volume values to generate ratio values associated with intervals corresponding to depth levels of the reservoir, generating, by the computing device, a fractional flow graphical representation including the ratio values associated with the intervals corresponding to the depth levels of the reservoir, utilizing, by the computing device, the fractional flow graphical representation including the ratio values to determine saturation values associated with the intervals corresponding to the depth levels of the reservoir, and generating a saturation graphical representation including the saturation values.

Abstract: Embodiments described herein include a system for generating a drainage radius log per well that includes a computing device that receives well data associated with a plurality of wells, utilizes the well production data to calculate a value for cumulative liquid produced by each of the plurality of wells for a predetermined time period, and utilizes at least a portion of the well data to calculate a fractional contribution for each of the plurality of wells. In some embodiments the computing device utilizes the value for cumulative liquid produced for each of the plurality of wells and the fractional contribution to calculate a cumulative liquid production for each of the plurality of wells, utilizes the cumulative liquid production to calculate the drainage radius log for each of the plurality of wells, and outputs the drainage radius log for display.

Abstract: Embodiments described herein include a system for generating a drainage radius log per well that includes a computing device that receives well data associated with a plurality of wells, utilizes the well production data to calculate a value for cumulative liquid produced by each of the plurality of wells for a predetermined time period, and utilizes at least a portion of the well data to calculate a fractional contribution for each of the plurality of wells. In some embodiments the computing device utilizes the value for cumulative liquid produced for each of the plurality of wells and the fractional contribution to calculate a cumulative liquid production for each of the plurality of wells, utilizes the cumulative liquid production to calculate the drainage radius log for each of the plurality of wells, and outputs the drainage radius log for display.

Abstract: A method for determining a plurality of saturation values is provided. The method accessing, by a computing device, data describing a plurality of fluid volume values associated with a reservoir, the plurality of fluid volume values include a plurality of cumulative water volume values and a plurality of cumulative hydrocarbon values, utilizing, by the computing device, the data describing the plurality of fluid volume values to generate ratio values associated with intervals corresponding to depth levels of the reservoir, generating, by the computing device, a fractional flow graphical representation including the ratio values associated with the intervals corresponding to the depth levels of the reservoir, utilizing, by the computing device, the fractional flow graphical representation including the ratio values to determine saturation values associated with the intervals corresponding to the depth levels of the reservoir, and generating a saturation graphical representation including the saturation values.

Abstract: A method for predicting oil flow rates is provided. The method includes accessing historical data from a plurality of databases, accessing historical perforation data and historical reservoir properties data from a simulation model, and determining fluid flow values and rock quality index values associated with perforated intervals of the plurality of wells. The method further includes corresponding the fluid flow values and rock quality values to the well production data, training, using the plurality of input values, a machine learning model for predicting oil flow values at perforated intervals of a plurality of target wells, predicting, using the trained machine learning model, the oil flow values at the perforated intervals of the plurality of target wells, and generating a synthetic production log that includes the predicted oil flow values at the perforated intervals of the plurality of target wells.