A method, comprising: stimulating a reservoir using a fracturing and fracture propping treatment stimulation process; obtaining data that characterizes the stimulated reservoir or from which the stimulated reservoir can be characterized; incorporating the obtained data into a field scale 3D reservoir model; predicting a cumulative production Q of the stimulated reservoir using the field scale 3D reservoir model which incorporates the obtained data; wherein the data are selected from the group consisting of attributes inverted from seismic data, regional geology, well logs, and microseismic data,the inverted attributes include one or more of elastic properties, reservoir properties, and azimuthal anisotropy properties, and the seismic data is prestack seismic data; characterized in that the method further comprises: - producing 3-D volumes of elastic properties, reservoir properties, and fracture densities of the stimulated reservoir; - inputting the 3-D volumes of elastic properties and reservoir properties into a stress model, and predicting a 3-D stress state of the formation using an output of the stress model; - inputting the 3-D volumes of elastic properties and the 3-D stress state of the formation into a network fracture propagation model; - predicting a productive propped fracture surface area A using an output of the network fracture propagation model; and - predicting the cumulative production Q based on predicting the productive propped fracture surface area A made by the fracturing treatment stimulation process. stimulating a reservoir using a fracturing and fracture propping treatment stimulation process; obtaining data that characterizes the stimulated reservoir or from which the stimulated reservoir can be characterized; incorporating the obtained data into a field scale 3D reservoir model; predicting a cumulative production Q of the stimulated reservoir using the field scale 3D reservoir model which incorporates the obtained data; wherein the data are selected from the group consisting of attributes inverted from seismic data, regional geology, well logs, and microseismic data,the inverted attributes include one or more of elastic properties, reservoir properties, and azimuthal anisotropy properties, and the seismic data is prestack seismic data; characterized in that the method further comprises: - producing 3-D volumes of elastic properties, reservoir properties, and fracture densities of the stimulated reservoir; - inputting the 3-D volumes of elastic properties and reservoir properties into a stress model, and predicting a 3-D stress state of the formation using an output of the stress model; - inputting the 3-D volumes of elastic properties and the 3-D stress state of the formation into a network fracture propagation model; - predicting a productive propped fracture surface area A using an output of the network fracture propagation model; and - predicting the cumulative production Q based on predicting the productive propped fracture surface area A made by the fracturing treatment stimulation process. - producing 3-D volumes of elastic properties, reservoir properties, and fracture densities of the stimulated reservoir; - inputting the 3-D volumes of elastic properties and reservoir properties into a stress model, and predicting a 3-D stress state of the formation using an output of the stress model; - inputting the 3-D volumes of elastic properties and the 3-D stress state of the formation into a network fracture propagation model; - predicting a productive propped fracture surface area A using an output of the network fracture propagation model; and - predicting the cumulative production Q based on predicting the productive propped fracture surface area A made by the fracturing treatment stimulation process.