Enhanced recovery

Low Polymer Retention Possible in Flooding of High-Salinity Carbonate Reservoirs

In this study, the authors show that high-temperature, high-salinity polymers can exhibit low adsorption and retention in carbonate reservoir rock at ultrahigh salinity conditions.

Experimental setup for retention experiments.
Fig. 1—Experimental setup for retention experiments. BPR=backpressure regulator.

Polymer flooding has been a successful enhanced-oil-recovery method in sandstone reservoirs for decades. Extending polymer flooding to carbonate reservoirs has been challenging because of adsorption loss and polymer availability for high-temperature, high-salinity (HT/HS) reservoirs. In this study, the authors establish that HT/HS polymers can exhibit low adsorption and retention in carbonate reservoir rock at ultrahigh salinity conditions.

Introduction

Retention is a key factor for polymer propagation and acceleration of oil production by polymer flooding. In the complete paper, the authors consider HT/HS applications for carbonate reservoirs.

SPE_logo_CMYK_trans_sm.png
Restricted Content
We're sorry, but this content is reserved for SPE Members. If you are a member, please sign in for access. If you are not a member and you find JPT content valuable, we encourage you to become a part of the SPE member community.