Parameter Analysis of Polymer on Sandstone Reservoir in Indonesia: An Experimental Laboratory Study

Abstract

Polymers are often used to increase oil recovery by improving sweeping efficiency. Screening was carried out as a first step in evaluating the test parameters of several polymers of the Hydrolized Polyacrylaamide (HPAM) type in fluid and sandstone reservoir rocks. The test was carried out using a reservoir fluid classified as light oil (35°API) and at a reservoir temperature (60°C).

There are 5 types of HPAM polymers, namely A1, F1, F2, F3 and P1. The test parameters carried out on these 5 types of polymer include compatibility test for formation water. The rheology polymer test includes concentration vs Tres, shear rate vs viscosity which aims to determine the type of polymer solution being tested is a non-Newtonian or pseudoplastic fluid group. Thermal stability test of polymer for 60 days to determine the stability of the polymer solution whether it is degraded or stable. Filtration testing with criteria FR value < 1.2, screen factor test and adsorption testing using the static method with a standard limit of adsorption value < 400 µg/gr and polymer injectivity test.

From these tests, scoring (range 0-100) was carried out to determine polymer candidates in polymer flooding testing. The F1 polymer candidate for the sandstone reservoir was obtained with a score of 82.25. From the results of the rheology test, the F1 polymer concentration was 2000 ppm. For thermal degradation for 60 days, the polymer F1 2000 ppm experienced a degradation of 15.5%. The results of the F1 2000 ppm polymer static adsorption test were 54.8 µg/gr. For the filtration ratio (FR) value of 1 and the injectivity test results (residual resistance factor / RRF) of 1.With the RRF = 1 value indicating rock permeability after injection of polymer F1 2000 ppm, it tends not to experience plugging due to injection of polymer solution.