Abstract: Partitioned volume fracturing has been applied in 118 wells in 11 tight conglomerate reservoirs in Mahu oilfield, proving the technique's suitability and operability. However, the best matching between rational fracturing parameters and optimal production results is still uncertain. In order to define the rational engineering technical parameters to guide the subsequent horizontal well fracturing design and also improve the comprehensive benefits of tight conglomerate reservoir development, the adaptability of horizontal well volume fracturing was studied through correlating the production data (e.g., post-fracturing production and pressure) to the fracturing engineering parameters (e.g., volume fracturing method, completion fracturing process, fracture parameters, fracturing scale and fracturing materials). The results show that the rational fracture spacing, sanding rate and sand-to-liquid ratio are 25-35 m, 1.2-1.5 m³/m, and 1:17-1:20 respectively for normal pressure reservoirs with poor physical properties, and about 40 m, 1.0-1.2 m³/m, and 1:15-1:17 respectively for abnormally high-pressure reservoirs with good physical properties. In addition, it is proved that precise fixed-point and controlled fracturing stimulation can increase post-fracturing production by more than 20% under the same conditions. In the block where the reservoir depth is less than 3500 m and the closing stress is lower than 55 MPa, quartz sand can effectively replace ceramsite, so it is promising for wider application.

Key words: Mahu oilfield, tight conglomerate reservoir, volume fracturing, adaptability evaluation