For homogenous tight carbonate reservoirs, the fracture surface mainly formed uniform etching pattern after acid etching and supported by a small amount of convex point. When rock is soft or in formation closure stress, those supporting points are easily broken or embedded into the fracture surface and consequently unable to form effective self-supporting flow channel. To better understand the improvement of conductivity after adding proppant in acid etching fracture, we deeply analysis the influence of sanding concentration, proppant particle size, non-Darcy effects and closure stress on acid etching fracture conductivity. The experimental results show that the conductivity of unpropped fracture drop rapidly with the increase of closure pressure, at a closure stress of 34.5MPa, fracture conductivity is reduced less than 2% of the initial conductivity and unable to meet the requirements of reservoir stimulation. Sand-adding fracture conductivity at formation closure stress is 3 to 7 times higher than self-supporting fracture conductivity. The bigger proppant can provide higher conductivity and should be selected if the acid fracturing conditions allow. Proppant-carrying acid fracturing technology was performed on well PG4 with a gas production rate of 6.314×10₄m₃/d, which confirms the necessity of adding additional support points in acid fracturing in homogeneous tight carbonate reservoirs.