Pursuing new alternatives to develop and produce sands B1 and B4 together, belonging to the reservoir VLG-3729 of Moporo Field located in western Venezuela, different exploitation schemes were evaluated, where intelligent completions have been highlighted. A pilot well with inflow control valves (ICVs) was proposed with the goal of maximizing the well oil production, avoiding cross-flow, minimizing operational risks and well interventions(coil-tubing operations), leading to better reservoir management.
To evaluate the intelligent completion technology, an Integrated Asset Model (IAM) was implemented. This model was divided in two sections: the first section involves the reservoir model using a reservoir simulator, which includes the representation of the ICVs through the multi-segment wells option; the second section represents the fluid flow in the well and pipelines from the couple point to the sink including the artificial lift system (Electrical Submersible Pump, ESP) through a network simulator. Both sections were coupled taking an intermediate point between the ESP and ICVs as a coupled node.
The differences using a stand alone model and a coupled model were analyzed. Given that in both models the main constraints are handled in different ways, the calculated liquid production trend is different for each model. The stand alone model is constrained by maximum liquid rate and minimum bottom hole pressure (BHP), while the BHP constraints on the coupled model is calculated dynamically by the production system. In this case, the stand alone reservoir model leads to an optimistic production profile. These results show the advantage in the use of an IAM, taking into account the network constraints to obtain more accurate results.
To evaluate the performance of the smart well, several sensitivities to the coupled model were made, changing the opening valves position at the beginning of the forecast. An increment in the cumulative oil production was observed when the cross flow between sands were not allowed.
Introduction
The VLG-3729 Moporo field is located between Zulia and Trujillo states (Western of Venezuela). It was discovered in 1988 by an advanced well (VLG-3729) from a neighbor reservoir. See Fig. 1. Six regions are defined by two primary faults and several secondary faults, which have compartmentalized the field. The depths vary from 15000 and 17000 ft, initial pressure of 7500 psi, net thickness from 400 to 500 ft, porosity from 10 to 15% and effective permeability from 50 to 500 md. It represents the most prolific and potential field from Maracaibo Basin. Moporo field has a cumulative production at 320 MMSTB under natural depletion with reservoir temperatures range from 280 to 300 °F and 22 °API approximately. The field development currently consists of 96 wells (88 active, 5 inactive and 3 abandoned wells), which produce from two separated reservoirs: B-1 and B-4. B1 sand is under initial conditions with a 3500 STB/d as estimated potential, whereas B4 sand accounts 90% of total production with an initial production from 6000 STB/d. The driven mechanism has been identified as solution gas and water drive.
