Tight fractured carbonate reservoirs are difficult to obtain industrial oil and gas flow through conventional stimulation methods. The traditional stimulation techniques such as hydraulic fracturing and acid fracturing do not perform well in such reservoirs due to poor formation properties. Therefore, a novel stimulation technique named hybrid volume stimulation (HVS) is put forward. This technique consists of three stages, which are pad fluid fracturing, large-scale acid fracturing and proppant injection. The core idea of this technique is to create a complex fracture system with c conductivity to get further control of the reserves.In this study, laboratory tests were performed on reservoir rock samples to evaluate the stimulation effect and feasibility of HVS. Effects of pad fluid fracturing on carbonate rocks with pre-existing natural fractures were investigated. Then, features of acid dissolution on tight matrix and natural fractures in different cementing degrees were revealed. Moreover, fracture conductivity provided by different propping types was measured and the equivalent conductivity of the fracture system was calculated.The results showed that the natural fractures were extended and the induced fractures were created after pad fluid injection. Gelled acid could dissolve the cement in the partially cemented fractures and connect the fractures into one system. The propped fractures could provide enough conductivity under both high and low closure stress, while the un-propped conductivity was very limited. The acid-etched fractures might provide enough conductivity under low closure stress, however, as the closure stress increasing, it reduced to the same order of magnitude as un-propped ones. The equivalent conductivity of the fracture system was 3–4 times higher than that of the double-wing fracture, verified the feasibility and effect of HVS technique in tight fractured carbonate formations.