A method for identifying poor conductivities of fracture stages in reservoir systems for use in refracturing reservoir systems, which comprises: a) sampling an average effective fracture length from a distribution of average effective fracture lengths determined using real-time down-hole temperature and stress information from advanced monitoring techniques; b) selecting current pressure and temperature profiles from information provided by real-time sensors over a length of each fracture stage; c) performing history matching to determine a misfit using the current pressure and temperature profiles, the distribution of average effective fracture lengths, the sampled average effective fracture length and a computer processor; d) updating a static well model using the current pressure and temperature profiles, the distribution of average effective fracture lengths and the sampled average effective fracture length for the static well model; e) calculating a fracture conductivity for each fracture stage; f) selecting pressure and temperature profiles for a predetermined period of time over the length of each fracture stage; g) performing history matching using at least one pressure and temperature profile from the pressure and temperature profiles selected for the predetermined period of time, the distribution of any effective fracture lengths, the sampled average effective fracture length and the computer processor; h) updating the updated static well model, which represents a new updated static well model, using the at least one pressure and temperature profile from the pressure and temperature profiles selected for the predetermined period of time, the distribution of average effective fracture lengths and the sampled average effective fracture length for the updated static well model; i) calculating a Reynolds number for each fracture stage based on the new updated static well model; and j) identifying each fracture stage with poor fracture conductivity using at least one of the fracture conductivity and the Reynolds number calculated for each fracture stage. a) sampling an average effective fracture length from a distribution of average effective fracture lengths determined using real-time down-hole temperature and stress information from advanced monitoring techniques; b) selecting current pressure and temperature profiles from information provided by real-time sensors over a length of each fracture stage; c) performing history matching to determine a misfit using the current pressure and temperature profiles, the distribution of average effective fracture lengths, the sampled average effective fracture length and a computer processor; d) updating a static well model using the current pressure and temperature profiles, the distribution of average effective fracture lengths and the sampled average effective fracture length for the static well model; e) calculating a fracture conductivity for each fracture stage; f) selecting pressure and temperature profiles for a predetermined period of time over the length of each fracture stage; g) performing history matching using at least one pressure and temperature profile from the pressure and temperature profiles selected for the predetermined period of time, the distribution of any effective fracture lengths, the sampled average effective fracture length and the computer processor; h) updating the updated static well model, which represents a new updated static well model, using the at least one pressure and temperature profile from the pressure and temperature profiles selected for the predetermined period of time, the distribution of average effective fracture lengths and the sampled average effective fracture length for the updated static well model; i) calculating a Reynolds number for each fracture stage based on the new updated static well model; and j) identifying each fracture stage with poor fracture conductivity using at least one of the fracture conductivity and the Reynolds number calculated for each fracture stage.