ASP System Design for an Offshore Application in La Salina Field, Lake Maracaibo

Abstract

La Salina Field, on the eastern coast of Lake Maracaibo, Venezuela, was designated as a Laboratorio Integrado de Campo (Integrated Field Laboratory, or IFL) by PDVSA to evaluate the potential application of different EOR processes. One of the main goals at La Salina IFL was to evaluate the alkaline-surfactantpolymer (ASP) technology potential in an oil reservoir near the end of its waterflood life.La Salina produces a medium-gravity crude oil (25°API) from the LL-03/Phase III Miocene reservoir at 915 m (3,000 ft). The feasibility of applying the ASP technology was based on a series of experiments including fluid compatibility, chemical thermal stability, phase behavior, interfacial tension between crude oil and ASP solution, chemical retention by the porous media, and physical simulation with reservoir core samples. The laboratory design involved 23 commercial surfactants, five polymers, and two alkalis. Interfacial tension reductions in excess of 25,000-fold were observed for a variety of ASP solutions. Type II-and Type III phase behaviors were observed. Linear coreflood results indicate that high-molecular-weight, partially hydrolyzed polyacrylamide polymers can be injected into La Salina sand. Radial sandpack floods produced an average oil recovery of 45.6% original oil in place (OOIP) with water injection. Injection of 30% pore volume of ASP solution, followed by 30% pore volume of polymer drive solution, produced (on average) an additional 24.6% OOIP for an average total oil recovery of 70.2% OOIP.The design of the injection plant for La Salina is a challenging task because this will be the first offshore application of the ASP technology in the world. The initial decision for the plant design was to use an existing platform instead of a barge for the construction of facilities. As a result, critical parameters such as treatment sequence, equipment footprint, and storage space for injected and treatment chemicals were considered. Preparation and transport of a phase-stable ASP solution through the injection lines and into the reservoir are crucial. Designed chemical concentrations and physical characteristics must be maintained.

Surfactant-Polymer Coreflood Simulation and Uncertainty Analysis Derived from Laboratory Study

“…Otherwise, whether the prediction the simulation has good agreement can only be shown by the different scenarios of varying the slug size of the injected blended surfactant-polymer. This result has pointed to some researches carried out that have reported on similar cases, in which, in order to attain a chemical EOR flooding match, the end-point of the relative permeability needed to be changed intentionally [21][22][23]. In this research, the authors have employed Eq.…”

Physical and Numerical Simulations of Steamflooding in a Medium Crude Oil Reservoir, Lake Maracaibo, Venezuela

“…Using this model, numerical simulations of steamflooding were carried out to determine the technical feasibility of applying this technology to the 3 rd phase LL-03 reservoir (25° API). The location of this reservoir was reported in a previous publication 16 .…”

Integration of a Risk-Management Tool and an Analytical Simulator for Assisted Decision-Making in IOR

“…The example at hand referrers to the analysis of the Alkaline/Surfactant/Polymer (ASP) process in a sandy reservoir (La Salina in Lake Maracaibo) in Venezuela 15 . ASP has been tested in a number of fields [16][17][18] and it is becoming an attractive chemical method under the current price scenario.…”