Experimental investigation of polymer injectivity and retention under harsh carbonate reservoir conditions

Using starch graft copolymer gel to assist the CO2huff-n-puff process for enhanced oil recovery in a water channeling reservoir

“…When the polymers were injected into the porous media, the molecular coils deformed elastically according to the different sizes of the pore throats, which then caused a higher flow resistance for the polymer gelant. This result was also consistent with the idea proposed by Alfazazi et al 46 that the polymers might have good rheology in bulk experiments but end up with poor injectivity in porous media, whereas the SGC gelant was a predominantly viscous solution at low shear conditions. The molecular chains of starch could be easily arranged according to the size of pore throats, which then caused a lower flow resistance in the porous media.…”

Updated Perceptions on Polymer-Based Enhanced Oil Recovery toward High-Temperature High-Salinity Tolerance for Successful Field Applications in Carbonate Reservoirs

“…Dupuis et al produced comparable results in their investigations on these polymers [ 169 ]. Furthermore, various rheological investigations of ATBS-based polymer and injectivity on three carbonate rock samples revealed that these polymers need to be salinity tolerant [ 170 ]. Sandengen et al [ 171 ] published another crucial study that found that ATBS could suppress hydrolysis in AM-based polymers.…”

“…There are a few noteworthy recommendations that will aid operators in the appropriate design and planning of polymer-based EOR projects in carbonate reservoirs under harsh conditions, such as high temperature, high salinity, and low permeability. Several recent screening studies and core-flooding tests have led to these recommendations [ 42 , 62 , 65 , 67 , 70 , 71 , 88 , 119 , 120 , 128 , 129 , 150 , 155 , 162 , 163 , 164 , 169 , 170 , 171 , 172 , 173 , 175 , 176 ], along with the simulation runs and field pilots [ 42 , 44 , 78 , 88 , 104 , 169 , 176 , 202 , 203 , 204 , 205 , 206 , 207 , 212 ] in carbonate rocks. These following recommendations will aid in improved designs for field implementation and are intended to possibly resolve the challenges of high temperature, high salinity/hardness, and injectivity issues in low-permeability carbonate formations.…”

Adsorption of Welan Gum on Montmorillonite and Its Influencing Factors

“…There are many reasons for polymer retention in reservoirs, including polymer adsorption, mechanical retention, and hydrodynamic retention [27]. Among them, the damage caused by the adsorption of clay minerals is difficult to remove [28]. Quezada et al found that the hydrogen bond between HPAM and quartz sand promoted the increase in the adsorption capacity, while the adsorption capacity decreased significantly with the increase in inorganic salt content [29].…”