Integration between experimental investigation and numerical simulation of alkaline surfactant foam flooding in carbonate reservoirs

Author(s)

Silva, Joao Victor Gois ; Silveira, Bruno Marco Oliveira ; Ferrari, Jean Vicente ; Sampaio, Marcio Augusto

• Document type: Journal article
• Source: JOURNAL OF PETROLEUM EXPLORATION AND PRODUCTION TECHNOLOGY; v. 14, n. 10, p. 25-pg., 2024-07-29.

Abstract

In Brazil, pre-salt carbonate reservoirs are largely responsible for the current increase in oil production. However, due to its peculiar characteristics, increasing oil recovery by water injection is not enough. Therefore, we seek to evaluate the recovery potential using chemical methods (cEOR). Among these, the Alkali Surfactant Foam (ASF) method appears with high potential, a variant of Alkali Surfactant Polymers (ASP) without the problems presented by it. Therefore, this work presents an innovative methodology, which seeks to evaluate the potential for recovery with ASF in carbonate reservoirs by integrating experimental characterization and recovery prediction using reservoir simulation. For this, phase behavior and adsorption analyses were carried out. The experimental results provided key parameters for the simulation, such as optimal salinity, surfactant adsorption, foam mobility reduction factors. The results are from two case studies of AS and ASF flooding, using a section of UNISIM-II benchmark, using a one-quarter of five-spot model. Having the modelling for these cEOR methods defined, an optimization process for each method was applied, allowing a reliable comparison among the methods and over a base case of water injection, seeking the maximization of the net present value (NPV). As a result, in the experimental part, a low interfacial tension (IFT) value of 0.003 mN/m was achieved with a surfactant adsorption reduction of 17.9% for an optimal setting among brine (NaCl), alkali (NaBO2.4H2O), and surfactant (BIO-TERGE AS 40). In the reservoir simulation part, using a fast genetic algorithm in the optimization process, a NPV of US$ 14.43 million higher than the base case (water injection) and a 4.5% increase in cumulative oil production for the ASF injection case were obtained. Considering the analyses of production curves (cumulative oil production and oil rate) and oil saturation maps, a considerable oil production anticipation was observed, which was the main reason for NPV improvement, proving the high potential for application of the ASF method in carbonate reservoirs. (AU)

• FAPESP's process: 16/08801-0 - Optimization of Improved Oil Recovery through CO2-WAG Injection
• Grantee: Marcio Augusto Sampaio Pinto
• Support Opportunities: Regular Research Grants
• FAPESP's process: 17/15736-3 - Engineering Research Centre in Reservoir and Production Management
• Grantee: Denis José Schiozer
• Support Opportunities: Research Grants - Research Centers in Engineering Program