In this study, possibility of geological storage of CO₂ into an Iranian hydrocarbon reservoir is investigated as a method of enhanced oil recovery (EOR). For this purpose, a stainless steel sand packed model, containing rock and brine, was used to simulate the reservoir condition and CO₂ injection. Subsequently, CO₂–rock–brine interactions (dissolution and deposition of minerals) due to CO₂ injection, under reservoir pressure and temperature condition (136 bar and 80 °C), was studied with ion chromatography and pH measurement at time intervals of 7, 14 and 30 days. In addition, the rock structure was identified by X-ray diffraction analysis. Results showed that up to 14 days, pH and the concentration of cations (sodium, calcium, magnesium, and potassium) and anions (chloride and sulfate) were progressively increased. However, in 30 days, assays, both pH and concentration, were decreased compared to those of 14 days of test results. Consequently, the dissolution process was observed to be the dominant phenomenon in the early days; then, the deposition of secondary minerals became the main process during the performed test. Finally, in the case of selecting the right place for CO₂ injection, to avoid the porosity and permeability decrease near the well, this method can be used as a safe technique for CO₂ geological storage at specific time intervals in the studied oil reservoir.

在这项研究中，研究了将CO ₂地质储存到伊朗碳氢化合物储层中的可能性，以此作为提高采油率（EOR）的方法。为此，使用了一个包含岩石和盐水的不锈钢沙子填充模型来模拟储层条件和注入CO ₂。接着，CO ₂ -rock盐水相互作用（溶解和矿物质的沉积），由于CO ₂在储层压力和温度条件（136 bar和80°C）下，通过离子色谱法和pH测量以7天，14天和30天的时间间隔对注入量进行了研究。另外，通过X射线衍射分析鉴定了岩石结构。结果表明，在长达14天的时间里，pH值以及阳离子（钠，钙，镁和钾）和阴离子（氯离子和硫酸根）的浓度逐渐增加。但是，与14天的测试结果相比，在30天内，pH和浓度的测定均降低了。因此，早期发现溶解过程是主要现象。然后，次生矿物质的沉积成为进行测试的主要过程。最后，在为CO ₂选择合适的位置的情况下为了避免井附近的孔隙率和渗透率降低，该方法可以用作在研究的油藏中按特定时间间隔进行CO ₂地质封存的安全技术。