This work shows the realization of a 3D static and dynamic model with feasibility analysis and conceptual planning in the field of "La Itala" in Los Perales. Incorporate in one unique project feasibility and conceptual model is the principal benefits of this method because until now we haven't this kind of project in this all field. To perform this project, it was used some basic data of the wells, like SP and resistivity and a petrophysical model. To do the feasibility analysis we use wells basics curves envelops. Combining with core analysis a static facies model was generated. Using averages of rock and fluid parameters along with the history of production and injection, a dynamic model was initialized. This model permits to do a "History Match" at field level. This allowed visualizing the evolution in time of displacement of fluids, product of the water injection. The conclusions of this model define continuity with the conceptual model using a complete petrophysical study (VCL-Phie and Sw). Combination of the results of SP and short resistivity envelopes yielded to a first approximation of a Vclay. From there a binary log was generated. Settle the same curve with a vertical proportion curve; reference levels used to separate the model in zones were defined. The study of cores fostered a relationship between facies and resistivity. To make a reliable 3D structural model the control was made by some surfaces created on well tops by correlation. In this static model were charged all wells data available (perforations, facilities, production and injection). Along with rock properties and fluid average, the model was initialized. At this stage of visualization, a quick historical setting, at field level, injection and production served to understand the behavior of fluids in the reservoir. This understanding in the changes of water saturation turns to be a very important input for the next phase of conceptualization. Having a static and dynamic visualization model purchase in both ways the conceptualization phase, whether or not pass to the next stage. Everything done in the first stage is the starting point of the next (Front End Loading - FEL). The FEL methodology is deeply rooted in the DNA of YPF. In this case, with software who allowed enhancing this work process, creating a unique project where all available parameters are incorporated, with the possibility of being used in the different phases of the study. At the same time, each analysis on the project, adds value to the next step. This work allowed to reservoir engineer of this field to improve the oil recuperation factor.

The aim of this work is to evaluate the desirability of conducting the History Matching using flow lines instead of traditional simulation. The results are very encouraging. The simulation time was reduced to a 10% from its original value, with a very good match. This was subsequently confirmed with a traditional simulation. The San Jorge basin (CGSJ), located in southern Argentina, extends over the central part of the Patagonian region. The sedimentary fill of the basin is related to different rift and sag tectonic phases, from Triassic to Cretaceous. During Late Cretaceous-Early Tertiary, a marine transgression from the Atlantic developed. Tertiary sediments completed the basin fill. Sediments from continental rivers form a huge overlying of fluvial-shallow lacustrine units deposited under late sag conditions. These units contain the reservoirs that host the hydrocarbon accumulations of the basin. The study area to be developed by Secondary Recovery has more than 250 reservoirs and 300 drilled well. The drenage radio is about 150 mts. The average production of each well is around 15 Bbl/d. As part of the Reservoir Caracterization, a high-resolution reservoir model was build. The model contains 5.4 million cells (1.1 are active) with 290 producing layers and 260 wells. Production started mid 1993 (22 years of History). Water flooding started 2002 when 21 wells were converted to injectors. It's a simple grid with 50 to 50 meters by cell. A conventional simulation run takes 12 hours. No assisted history matching was possible, due to the size of the model. With the use of a fast flow simulation technique, streamlines, the time was reduced to 2.5 hours. This makes possible to work over the simulation parameter. With this normal simulation time, enough runs were done to match pressure behaviors and field productions. So, a standard history matching workflow was used with the exception of flow lines to perform the simulation runs. The use of stream lines reduced nine times the standard simulation time. Thanks to this, it was possible to manually iterate the model parameters, doing each time a new simulation run to evaluate results. This work methodology allowed the correct understanding of Reservoir drainage mechanism. With all this, history match was done in a reasonable time. The absolute difference in liquid production was less than 12%. Finally, a conventional run was performed to verify the consistency between the two methodologies. In this case, the difference between both runs is imperceptible. This confirms that the use of strem lines is an excellent tool to adjust big size models.