Innovations of Complex Geology in Mature Basin "Talara" (More Than 100 Years of Development) to Generate Viable Projects in Block 4 – Peru

Abstract

The Talara basin was discovered in the year 1920, since then it has been the oldest basin in Peru and Latin America in hydrocarbon exploitation. The complexity in structural geology and stratigraphy become an opportunity for improvement.The study area has 8 wells drilled by lower Pariñas formation of the 50's, with productions that were not commercial. In the 2016-2017 drilling campaign in this area, 05 wells were drilled , that are sustainable with marginal economies as part of extension of development areas. In these 05 new wells has been taken well logs (Den&Neu) to calculated porosity, clayness and water saturation curves. Regarding the sedimentary model, the model of the lower Pariñas formation is generated in block of exploitation in which there are no different reasons fo the study area to be different as a reservoir and therefore in productive behavior. Stratigraphic correlations are made finding continuity of the main productive sand intervals. The 3D structural model is generated, from the generation of 2D structural maps to different levels of the lower Pariñas formation and control points of the main faults. The faults are truncated and the displacements are compensated, and the model of horizons is made. Then the petrophysical information is loaded by well, the upscaling of the porosity and arcillosity curves is performed. For each zone generated, the dispersion spectrum is evaluated according to trend maps of the deposition in block of development, populating the cube with geostatistical criteria With the probabilistic calculation of the POES it is possible to generate 03 scenarios "P10, P50 and P90" with which the theoretical recovery factor can be reached. The presence and reservoir quality of the Lower Pariñas Formation have been demonstrated, categorizing them as tidal channel environments. The probabilistic POES is P10: 14 MMBLS, P50: 18.04MMBLS, P90: 22.2 MMBLS. The theoretical recovery factor is 15%, and the current recovery factor (EUR of new wells) is 5% (with P50), taking 10% to develop, which implies drilling 20 additional wells to 12 acres at least and a maximum of 47 wells with reduced acreaje. Before 05 wells were perforated the economic model was marginal with payout periods of up to 5/6 years. After the drilling of these wells, the economic model has changed, and contributed financially to support oil prices during the years 2016 and 2017, focusing the largest number of locations in this area for the 2018 campaign.

AAPG Datapages/Search and Discovery Article #90332 © 2018 AAPG International Conference and Exhibition, Cape Town, South Africa, November 4-11, 2018