ABSTRACT A study of fracture stimulations in two South Texas oil fields indicated that proppant flowback was a major problem. This paper examines thirty-four stimulations that used 100% sand as the proppant and thirty-five stimulations that used a tail-in of resin coated sand. In the Big Wells Field, thirty-one wells have been fracture stimulated using 100% sand as the proppant. These wells averaged 1.25 failures per well per year. In the North Government Wells Field, three wells have been fracture stimulated using 100% sand as the proppant. These wells averaged 5.40 failures per well per year. In order to reduce the incidence of proppant flowback while maintaining a high sand concentration, curable resin coated sand was substituted for the final 10-20% of the recommended amount of sand in the fracture stimulation. Once this resin coated sand is pumped into the fracture, it chemically bonds together to form a barrier against proppant flowback. In the Big Wells Field, thirty-one wells have been fracture stimulated using a tail-in of resin coated sand. These wells averaged 0.19 failures per well per year. In the North Government Wells Field, four wells have been fracture stimulated using a tail-in of resin coated sand. These wells have averaged 2.43 failures per well per year. Characteristics of wells with proppant flowback were examined with respect to bottomhole pressure, waterflood response, and acid stimulation. A comparison was made between wells stimulated with 100% sand and wells stimulated with a tail-in of resin coated sand using decline curves and post fracture stimulation bottomhole pressure buildups. Based on the results of these sixty-nine fracture stimulations, it can be concluded that a tail-in of resin coated sand is an effective method of controlling proppant flowback following fracture stimulation.