Salt precipitation due to formation drying is a critical secondary alteration process that significantly impairs reservoir injectivity in the context of CO2 geological storage. In this work, salt precipitation during CO2 injection is reviewed primarily through various experimental studies. First, the experimental systems for salt precipitation studies, namely core-flooding, microfluidic-chip, static batch, and surface drying experimental systems, have been described to present their respective experimental procedures and merits, as well as corresponding applications. Subsequently, following the general description of the formation mechanisms of salt precipitation, the macro and micro salt distribution patterns at the reservoir and pore scales have been summarized. Finally, and most importantly, this study provides a comprehensive analysis of the controlling factors for salt precipitation, categorized into four different groups, according to the brine, rock, gas, and injection scenario aspects. Among all these factors, brine salinity, CO2 injection rate and initial reservoir properties are considered the most critical in determining the amount and distribution of precipitated salts and the degree of injectivity impairment. The effects of multi-scale reservoir heterogeneity and rock wettability on salt precipitation are attracting growing consideration, while the brine and gas composition studies are receiving less attention due to their relatively minor influences on reservoir alteration. Due to the limited specimen sizes, the ex-situ brine replenishment may be underestimated in core-flooding and microfluidic-chip experiments. This may result in a potentially significant underestimation of the volume of local salts and the potentially inaccurate prediction of the drying process during CO2 injection in many such experiments., Funding was provided by China University of Petroleum (East China) to the Independent Innovation Research Project 22CX06004A, by the Qingdao Municipal Bureau of Science and Technology to the Natural Science Project 23-2-1-55-zyyd-jch, by the Department of Science & Technology of Shandong Province to the Natural Science Project ZR2023QD093, and by the National Natural Science Foundation of China to the Natural Science Project 42402140. SA acknowledges the Open Research Project SKLDOG2024-KFYB-02 funded by the State Key Laboratory of Deep Oil and Gas and the Research Team Cultivation Program 2023QNT004 funded by Shenzhen University. HH acknowledges funding from Norway Grants (UMO2019/34/H/ST10/00564) and EEA and Norway Grants (NOR/POLNORCCS/AGaStor/0008/2019-00). JA acknowledges funding from MICIU/AEI/10.13039/501100011033 and “ERDF/EU” (PID2022-140850OB-C22). AT acknowledges Grant PID2021-12246NB-C22 funded by MICIU/AEI/10.13039/501100011033, FEDER, EU, and the Catalan Council to the Grup Consolidat de Recerca Reconegut Geologia Sedimentària (2021 SGR-Cat 00349). EGR acknowledges funding from the DGICYT Spanish Project PID-2020-118999GB-I00 funded by MCIN/AEI/10.13039/501100011033) and the “Consolidación Investigadora” Grant CNS2023-145382 funded by MCIN/AEI/10.13039/50110001103 and European Union NextGeneration EU/PRTR., Peer reviewed