Mahu tight conglomerate reservoir is turning to the stage of benefit development, and it is necessary to carry out the optimization research on the rational fracturing treatment parameters of horizontal well groups. Therefore, by fully exploiting the function of the existing petroleum reservoir simulation, an integrated numerical simulation method and workflow combining fracturing and production were proposed. Taking the overall recovery degree of well groups based on the elastic development as the indicator, the sensitivity analysis of well spacing deployment and fracturing treatment parameters was carried out. Then the main control factors were identified based on the orthogonal design principle. The results show that the productivity of horizontal well groups increases first and then decreases with the increase of well spacing, cluster spacing and fracturing fluid intensity, and the sanding intensity is positively correlated with the productivity of well groups. The impact of the four factors on the overall recovery degree from high to low is well spacing, sanding intensity, fracturing fluid intensity and cluster spacing. The optimal parameter combination scheme is 250 m well spacing, 20 m cluster spacing, 30 m³/m fracturing fluid intensity, 3 m³/m sanding intensity, and the overall recovery degree in 5 years is 17.9%. The research results can provide technical support for the optimal fracturing design of tight oil horizontal well groups.