Integrating stimulation practices with geo-mechanical properties in liquid-rich plays of Eagle Ford Shale
在富液Eagle Ford开发区尝试了许多水力压裂设计技术。这项研究表明，由于区块内岩石地质力学应力和相关储层性质的变化，观察到不同结果。富液页岩的最佳处理与气态页岩的最佳处理有很大不同，这主要是因为多相流和较高粘度。
本研究提出了一种新的Eagle Ford页岩富液窗口处理流程。对整个区块多组数据进行审查和整合，作为3D水力压裂模拟器的输入，以模拟控制产量提高的关键压裂参数。然后将这些结果用于产量分析和预测、油井优化和经济模型中，将压裂设计与支撑剂的最佳分布进行比较，从而实现高初始产量和长期最终采收率。
该工作流程的一个关键重点是最大限度地增加支撑剂运移，以实现连续最佳的导流裂缝半长。通常，由于非常规沉积的复杂性，很难保持支撑剂充填与井筒的完全连通性。因此，裂缝网络的大部分潜力都丧失了。了解水力裂缝和岩石组构的相互作用有助于设计这种行为，以获得最佳结果。这些结果用于确定最佳井距，以便在选定的储层面积内有效开发。
目前，在Eagle Ford页岩地层的大部分地区，存在着许多具有两年以上生产历史的油井。本研究的结果用于比较现场生产的值，以证明在将储层和操作参数集成到裂缝设计中时，采用有效工作流程的重要性。使用本研究中提出的方法，可以正确理解和应用水力压裂模拟。
Abstract
Many of the techniques for hydraulically fracturing design were attempted in the liquidrich Eagle Ford developments. This study shows why different results were observed due to the variation of geomechanical stresses of the rock across a play and related reservoir properties. An optimum treatment for a liquids-rich objective is much different than that for a gas shale due primarily to the multiphase flow and higher viscosities encountered.
This study presents a new treatment workflow for liquids-rich window of Eagle Ford Shale. Review and integration of data from multiple sets across the play are used as input to a 3D hydraulic fracture simulator to model key fracture parameters which control production enhancement. These results are then used within a production analysis and forecast, well optimization, and economic model to compare treatment designs with the best placement of proppant to deliver both high initial production and long term ultimate recoveries.
A key focus for this workflow is to maximize proppant transport to achieve a continuous – optimum conductive – fracture half length. Often, due to the complexity of unconventional deposition, it is difficult to maintain complete connectivity of a proppant pack back to the wellbore. As a result, much of the potential of the fracture network is lost. Understanding the interaction of a hydraulic fracture and the rock fabric helps with designing this behavior to achieve the best results. These results are used to determine optimum well spacing to effectively develop within a selected reservoir acreage.
Currently, numerous wells exist with over two years of production history in much of the Eagle Ford shale formation. Results from this study are used to compare values from field production to demonstrate the importance of employing a diligent workflow in integrating reservoir and operational parameters to the fracture design. A proper understanding and application of hydraulic fracturing modeling is achieved using the methodology presented in this study.
