Abstract Recent core-lab study of Marcellus Shale illustrated that effect of gas slippage and matrix compaction are significant on gas production because of substantial reservoir pressure depletion, especially during the late time of gas production. However, the impact of gas slippage and matrix compaction on gas recovery evaluation and hydraulic fracturing design is still not clearly understood and systematically investigated. Additionally, such impact varies with production time and completion/production circumstances. Therefore, it is critical to develop a laboratory-modeling based approach that properly characterizes the two permeability effects and evaluates their impact on well production evaluation and hydraulic fracturing design. In this study, a comprehensive parametric study is conducted by running reservoir simulations using empirical permeability correlations developed from core-lab tests under different confining stress and pore pressure conditions. Simulations of different case scenarios are run in two contrast groups. One group considers the effect of gas slippage and matrix compaction on gas production and the other group ignores the two effects. By comparing the simulated gas production, critical conductivity, and proppant pumping amount/cost of the two contrast groups, a better understanding of the effect of gas slippage and geomechanics on shale gas well performance and hydraulic fracturing design can be developed for operators. The results show that ignoring the two permeability effect in reservoir simulation leads to an overestimation of gas production evaluation, which is up to 11% for Marcellus Shale. It also leads to an over-design of proppant pumping amount, resulting in early staging, screening-out, and excessive pumping cost. Calculations further show that, an average of over 2 million dollars can be wasted for fracturing a single horizontal well in Marcellus Shale if excluding the two effect from a fracturing design. The two effects are more significant for lower BHP, longer hydraulic fracture, and larger stage spacing conditions.

中文翻译：

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基于实验和储层模拟的气体滑脱效应和基质压实效应对页岩气产量评价及水力压裂设计的研究

摘要 最近对马塞勒斯页岩的岩心实验室研究表明，由于大量的储层压力耗竭，尤其是在产气后期，气体滑脱和基质压实对产气量的影响是显着的。然而，气体滑脱和基质压实对采气率评价和水力压裂设计的影响仍不清楚和系统研究。此外，此类影响因生产时间和完成/生产情况而异。因此，开发一种基于实验室建模的方法来正确表征两种渗透率效应并评估它们对井产量评估和水力压裂设计的影响至关重要。在这项研究中，综合参数研究是通过在不同围压和孔隙压力条件下使用岩心实验室测试得出的经验渗透率相关性进行储层模拟来进行的。不同案例场景的模拟在两个对比组中运行。一组考虑了气体滑脱和基质压实对产气量的影响，另一组忽略了这两种影响。通过比较两组的模拟产气量、临界导流率和支撑剂泵送量/成本，可以为操作人员更好地了解气体滑脱和地质力学对页岩气井性能和水力压裂设计的影响。结果表明，在储层模拟中忽略二次渗透效应会导致产气评价的高估，马塞勒斯页岩的比例高达 11%。还会导致支撑剂泵送量设计过度，造成提早分期、筛除、泵送成本过高。进一步计算表明，如果从压裂设计中排除这两种影响，在马塞勒斯页岩中压裂单口水平井平均会浪费超过 200 万美元。对于较低的 BHP、较长的水力压裂和较大的级间距条件，这两种影响更为显着。