The U.S. Geological Survey (USGS) national assessment of carbon dioxide (CO₂) storage capacity evaluated 192 saline Storage Assessment Units (SAUs) in 33 U.S. onshore sedimentary basins that may be utilized for CO₂ storage (see USGS Circular 1386). Similar to many other available models, volumetric analysis was utilized to estimate the initial CO₂ injection and storage capacity of these SAUs based on aquifer characteristics and buoyant and residual trapping. The factor being almost always overlooked in most CO₂ storage capacity models is that many of the evaluated SAUs contain large numbers of both conventional and unconventional discovered and undiscovered oil and gas reservoirs. The hydrocarbon production and pressure distribution of the resident oil and gas reservoirs may be negatively influenced by the propagated CO₂ plume and pressure front resulting from a CO₂ injection and storage operation in the surrounding SAU.

To have a more realistic and accurate estimation of CO₂ injection and storage capacity in saline formations, a model was previously developed that considers the CO₂ injectivity of a given formation, underground pressure build-up limitations imposed by the rock fracturing pressure and the presence of hydrocarbon reservoirs within these aquifers. The developed method estimates the pre–brine extraction, pressure-limited CO₂ injection and storage capacity of a saline formation by applying 3D numerical simulation only on the effective injection area (A_eff) surrounding each CO₂ injection well utilizing TOUGH2-ECO2N simulation software.

美国地质调查局（USGS）对二氧化碳（CO ₂）储存能力的国家评估评估了美国33个可用于CO ₂储存的陆上沉积盆地中的192个盐分储存评估单位（SAU）（请参阅USGS通告1386）。类似于许多其他可用模型，利用体积分析基于含水层特征以及浮力和残留捕集来估计这些SAU的初始CO ₂注入和存储能力。大多数CO _2中几乎总是忽略该因素存储容量模型是，许多评估的SAU都包含大量常规和非常规的已发现和未发现的油气藏。驻留的油气储层的碳氢化合物生产和压力分布可能会受到周围SAU中CO ₂注入和存储操作所产生的传播的CO ₂羽流和压力前缘的不利影响。

为了更准确，更准确地估算盐岩层中的CO ₂注入量和储存能力，以前开发了一个模型，该模型考虑了给定地层的CO ₂注入量，岩石压裂压力和存在的地下压力形成限制。这些含水层中的碳氢化合物储层的数量。通过使用TOUGH2-ECO2N模拟软件，仅对每个CO ₂注入井周围的有效注入面积（A _eff）进行3D数值模拟，从而开发出的方法可以估算盐水的盐水提取，有限压力的CO ₂注入和储藏能力。。