The productivity of wells can be significantly enhanced through multi-stage hydraulic fracturing of horizontal wells, though there is notable variability in the production uplift across different wells or stages. Understanding the geometries of hydraulic fractures is pivotal to discerning the cause of this variation. Currently available methods for monitoring fracture geometry are expensive and do not support dynamic, well-specific monitoring. Conversely, the data volume from fracturing pumping curves is extensive and easily obtainable. Yet, the current use of this data is rather limited. A pressing challenge lies in effectively harnessing this copious fracturing curve data to deduce vital reservoir parameters and to gain a deeper comprehension of hydraulic fracture geometries. This study delves into the characteristics of fracture pumping curves within the Mahu conglomerate reservoir. It identifies the complexity of fractures and the occurrence of sand plugging at the fractured stage by analyzing the water hammer effects evident in shut-in curves. A shut-in curve analysis method for conglomerate reservoirs in the Mahu region is proposed, grounded in fractal theory and transient seepage theory. This approach amalgamates micro-seismic monitoring outcomes to ascertain the total length of hydraulic fractures and other pertinent details via shut-in curve inversion. The total fracture lengths deduced through the proposed method aligns with the results of integrated fracturing simulations and can serve as an efficient metric for evaluating fracturing efficacy.