A good reservoir’s dynamic characterization is key for a successful field development plan. In conventional reservoirs that was traditionally performed by a series of tools in which well tests were applied to get reservoir pressure and permeability. Because of the extremely low permeability of shale and tight rocks, classical well testing is no longer a practical way to estimate those parameters, leaving DFITs (Diagnostic Fracture Injection Tests) are one of the few methodologies to do so. However, DFITs interpretation by conventional approach is sometimes difficult because it requires to reach specific flow regimes (pseudolinear or pseudoradial) during the time of declination to correctly estimate the reservoir parameters. Additionally, de duration of DFITs must compete against the well’s completion efficiency. All of this, results frequently in short shut-in times leading to a poor DFIT’s interpretation efficiency, i.e., low percentage of tests with confident reservoir data (closure pressure, reservoir pressure and transmissibility). In 2014, David Craig presented a new method for DFIT analysis based on type curves (SPE-168988) which its main advantage is that no specific flow regime is needed to estimate reservoir pressure and permeability overcoming the principal problem of the holistic approach. This new methodology also provides an alternative way to estimate closure pressure, which is particularly useful when the classical technique is ambiguous, something that frequently occurs in areas with a high tectonic components. This paper describes how using type curve methodology, YPF increased the number of valid results from DFITs improving the characterization of conventional and unconventional reservoirs from different basins. Since the application of this methodology, several DFITs have been successfully estimated, providing better data availability for development plans.