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: Systems and methods of estimating well parameters are disclosed. In one embodiment, a method of estimating well parameters includes receiving a plurality of wells, each well defined by a plurality of well attributes, receiving a plurality of historic wells, each historic well of the plurality of historic wells defined by a plurality of historic well attributes, and comparing the plurality of well attributes of the plurality of wells with the plurality of historic well attributes of the plurality of historic wells. The method further includes selecting one or more matched historic wells based at least in part on a similarity between the plurality of well attributes for an individual well with the plurality of historic well attributes of the one or more matched historic wells, and calculating one or more well parameters based at least in part on the one or more matched historic wells.

Abstract: Systems and methods of estimating well parameters are disclosed. In one embodiment, a method of estimating well parameters includes receiving a plurality of wells, each well defined by a plurality of well attributes, receiving a plurality of historic wells, each historic well of the plurality of historic wells defined by a plurality of historic well attributes, and comparing the plurality of well attributes of the plurality of wells with the plurality of historic well attributes of the plurality of historic wells. The method further includes selecting one or more matched historic wells based at least in part on a similarity between the plurality of well attributes for an individual well with the plurality of historic well attributes of the one or more matched historic wells, and calculating one or more well parameters based at least in part on the one or more matched historic wells.

Abstract: A system for creating a 4D guided history matched model may include a network of saturation sensors and a model processing hub. The saturation sensors may identify water production rates. The model processing hub may be in communication with the network of saturation sensors and may include a reservoir simulation model and a processor. The processor of the model processing hub may build a 4D saturation model, compare the reservoir simulation model and the 4D saturation model to generate a saturation ?, calculate updated permeability distribution data, and update the reservoir simulation model with the updated permeability distribution data to create the 4D guided history matched model. A method of creating a 4D guided history matched model may include comparing a reservoir simulation model and a 4D saturation model, calculating updated permeability distribution data, and updating the reservoir simulation model to create the 4D guided history matched model.

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: Systems and methods for economically evaluating multiple oil and gas field development scenarios are disclosed. In one embodiment, a method of evaluating oil field simulation scenarios includes receiving a computerized simulation scenario output for at least one oil field scenario, calculating, using one or more processors, a well count for the at least one oil field scenario, calculating, using the one or more processors, a net present value of the at least one oil field scenario, calculating, using the one or more processors, a cumulative production for the at least one oil field scenario, and displaying, in a graphical user interface, a three-dimensional plot of the at least one oil field scenario. A first axis of the three-dimensional plot is well count, a second axis of the three-dimensional plot is net present value, and a third axis of the three-dimensional plot is cumulative production.

Abstract: Systems and methods for automatically generating drilling schedules are disclosed. According to one embodiment, a method of predicting rig movement between wells includes receiving historical well data regarding individual well types and historical rig data regarding individual rigs, and generating a Markov Chain model from the historical well data and the historical rig data. The Markov Chain model includes a plurality of states and a plurality of links between states. Each state of the plurality of states is a well class derived from the historical well data. Each link indicates a number of rigs that traveled between individual well classes. The method further includes determining, using the Markov Chain model, a probability of rigs moving between individual well classes, and predicting movement of individual rigs of a plurality of rigs between future wells based at least in part on the Markov Chain model.

Abstract: Systems and methods of estimating well parameters are disclosed. In one embodiment, a method of estimating well parameters includes receiving a plurality of wells, each well defined by a plurality of well attributes, receiving a plurality of historic wells, each historic well of the plurality of historic wells defined by a plurality of historic well attributes, and comparing the plurality of well attributes of the plurality of wells with the plurality of historic well attributes of the plurality of historic wells. The method further includes selecting one or more matched historic wells based at least in part on a similarity between the plurality of well attributes for an individual well with the plurality of historic well attributes of the one or more matched historic wells, and calculating one or more well parameters based at least in part on the one or more matched historic wells.

Abstract: A system for creating a 4D guided history matched model may include a network of saturation sensors and a model processing hub. The saturation sensors may identify water production rates. The model processing hub may be in communication with the network of saturation sensors and may include a reservoir simulation model and a processor. The processor of the model processing hub may build a 4D saturation model, compare the reservoir simulation model and the 4D saturation model to generate a saturation ?, calculate updated permeability distribution data, and update the reservoir simulation model with the updated permeability distribution data to create the 4D guided history matched model. A method of creating a 4D guided history matched model may include comparing a reservoir simulation model and a 4D saturation model, calculating updated permeability distribution data, and updating the reservoir simulation model to create the 4D guided history matched model.

Abstract: A segregated flow mechanism of oil and water usually takes place in the presence of strong gravity forces in subsurface environments, having specific geometrical and petrophysical properties undergoing simultaneous flow of multiphase fluids. The segregated flow of oil and water is modeled as a two-layer reservoir system, based on the observed data. Accurate estimates or measures of the values of phase mobility of oil and water, in addition to the actual flow capacity of the formation are provided. Reliable reservoir characterizations and reserve estimations are provided based on the in-situ conditions of oil and water in the reservoir.

Abstract: A segregated flow mechanism of oil and water usually takes place in the presence of strong gravity forces in subsurface environments, having specific geometrical and petrophysical properties undergoing simultaneous flow of multiphase fluids. The segregated flow of oil and water is modeled as a two-layer reservoir system, based on the observed data. Accurate estimates or measures of the values of phase mobility of oil and water, in addition to the actual flow capacity of the formation are provided. Reliable reservoir characterizations and reserve estimations are provided based on the in-situ conditions of oil and water in the reservoir.

Abstract: A measure of inter-reservoir cross flow rate between adjacent reservoir layers which are productive of hydrocarbons is determined. With passage of time, pressure differentials between reservoir layers can grow due to continuous production from an active layer. In addition, the flow area between an active layer and adjacent layers can grow with time for a given reservoir system. These changing pressure and flow conditions with time can contribute to substantial amounts of cross flow rates, which need to be accounted for when characterizing the commercial producibility of the active layer. The inter-reservoir cross flow rate is based on a measure of specific permeability and of cross flow rate within a reservoir layer which is obtained from pressure transient tests of the reservoir formations.

Abstract: A segregated flow mechanism of oil and water usually takes place in the presence of strong gravity forces in subsurface environments, having specific geometrical and petrophysical properties undergoing simultaneous flow of multiphase fluids. The segregated flow of oil and water is modeled as a two-layer reservoir system, based on the observed data. Accurate estimates or measures of the values of phase mobility of oil and water, in addition to the actual flow capacity of the formation are provided. Reliable reservoir characterizations and reserve estimations are provided based on the in-situ conditions of oil and water in the reservoir.

Abstract: A segregated flow mechanism of oil and water usually takes place in the presence of strong gravity forces in subsurface environments, having specific geometrical and petrophysical properties undergoing simultaneous flow of multiphase fluids. The segregated flow of oil and water is modeled as a two-layer reservoir system, based on the observed data. Accurate estimates or measures of the values of phase mobility of oil and water, in addition to the actual flow capacity of the formation are provided. Reliable reservoir characterizations and reserve estimations are provided based on the in-situ conditions of oil and water in the reservoir.

Abstract: Crossflow between two adjacent reservoir layers through leaky cement sheaths in offset wells during transient-pressure tests in one of the two reservoir layers is diagnosed and quantified. The obtained measures are determined based on individual well and layer properties. The pressure drawdown in the reservoir layer in which pressure transient testing is being performed is measured as a function of time. The longitudinal conductivity of a leaky cement sheath in an offset well and the pressure drawdown in the tested reservoir layer simultaneously control the crossflow rate to the tested reservoir layer from the adjacent reservoir layer at a given time.

Abstract: A segregated flow mechanism of oil and water usually takes place in the presence of strong gravity forces in subsurface environments, having specific geometrical and petrophysical properties undergoing simultaneous flow of multiphase fluids. The segregated flow of oil and water is modeled as a two-layer reservoir system, based on the observed data. Accurate estimates or measures of the values of phase mobility of oil and water, in addition to the actual flow capacity of the formation are provided. Reliable reservoir characterizations and reserve estimations are provided based on the in-situ conditions of oil and water in the reservoir.

Abstract: A segregated flow mechanism of oil and water usually takes place in the presence of strong gravity forces in subsurface environments, having specific geometrical and petrophysical properties undergoing simultaneous flow of multiphase fluids. The segregated flow of oil and water is modeled as a two-layer reservoir system, based on the observed data. Accurate estimates or measures of the values of phase mobility of oil and water, in addition to the actual flow capacity of the formation are provided. Reliable reservoir characterizations and reserve estimations are provided based on the in-situ conditions of oil and water in the reservoir.

Abstract: Crossflow between two adjacent reservoir layers through leaky cement sheaths in offset wells during transient-pressure tests in one of the two reservoir layers is diagnosed and quantified. The obtained measures are determined based on individual well and layer properties. The pressure drawdown in the reservoir layer in which pressure transient testing is being performed is measured as a function of time. The longitudinal conductivity of a leaky cement sheath in an offset well and the pressure drawdown in the tested reservoir layer simultaneously control the crossflow rate to the tested reservoir layer from the adjacent reservoir layer at a given time.

Abstract: A measure of inter-reservoir cross flow rate between adjacent reservoir layers which are productive of hydrocarbons is determined. With passage of time, pressure differentials between reservoir layers can grow due to continuous production from an active layer. In addition, the flow area between an active layer and adjacent layers can grow with time for a given reservoir system. These changing pressure and flow conditions with time can contribute to substantial amounts of cross flow rates, which need to be accounted for when characterizing the commercial producibility of the active layer. The inter-reservoir cross flow rate is based on a measure of specific permeability and of cross flow rate within a reservoir layer which is obtained from pressure transient tests of the reservoir formations.