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首页> 外文会议>Asia Pacific Oil Gas Conference >Geomechanical and Reservoir Integrated Hydraulic Fracturing Optimisation for a Tight Oil Reservoir: A Case Study from Offshore Vietnam
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Geomechanical and Reservoir Integrated Hydraulic Fracturing Optimisation for a Tight Oil Reservoir: A Case Study from Offshore Vietnam

机译：封闭油藏的地磁和储层集成液压压裂优化 - 以海上越南为例

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Producing tight oil reservoirs by hydraulic fracturing is especially challenging due to relatively low oil mobility. At the planning stage, an integrated approach is essential to optimise fracture parameters using a reliable geomechanical model and reliable reservoir simulations to predict the post-fracture productivity and the net present value (NPV). This paper presents such an integrated case study. The reservoir contained relatively clean sandstones interlaying only a few thin shale layers. A relatively low recovery was expected to yield a good positive NPV because production was planned using a nearby existing production facility. A geomechanical model was built using core, well log and drilling data characterizing the in situ stress, pore pressure and rock mechanical properties in the field. The reservoir properties were characterized from core-log calibration and PVT data from analogue reservoirs. The initial reservoir pressure was very close to the bubble point pressure. Thus, multiphase reservoir simulations were essential to predicting post-fracture production profiles. The study integrated geomechanical modeling, hydraulic fracturing design, reservoir simulations and economic assessments to investigate various well completion scenarios. Various scenarios included a single vertical fracture in a deviated well, an un-fractured 1,000 m horizontal openhole well and a 1,000 m horizontal well with multiple transverse fractures. The un-fractured horizontal openhole scenario required a life cycle wellbore stability assessment. The fractured horizontal well scenario required the optimisation of transverse fractures and their spacing. The production constraints included a 600 psi tubing head pressure, a maximum oil flow rate of 5,000 bbl/d and a maximum 5-year production period with preference for more accelerated recovery. The results from this integrated scheme enabled understanding of the impact of various well comple- tion scenarios on decision-making based on technical and economic issues. The lessons learned in the study can be a guide for optimal development of the target field and other similar fields.
机译：由于较低的油迁移率，通过液压压裂制造液压压裂尤其具有挑战性。在规划阶段，综合方法对于使用可靠的地质力学模型和可靠的储层模拟来优化裂缝参数，以预测断裂后生产率和净现值（NPV）。本文提出了这种综合案例研究。储层含有相对清洁的砂岩夹层仅少量薄页岩层。预计相对较低的恢复将产生良好的正面NPV，因为使用附近的现有生产设施计划生产。使用核心，井钻孔数据建立了地质力学模型，其特征在现场应力，孔隙压力和岩石力学性能中的原位应力，孔隙压力和岩石力学性能。储层特性是从模拟储存器的核心对数校准和PVT数据的特征。初始储层压力非常接近气泡点压力。因此，多相储层模拟对于预测断裂后生产型材至关重要。研究综合地质力学建模，液压压裂设计，水库模拟和经济评估，调查各种井完井方案。各种场景包括在偏离井中的单个垂直骨折，一个未破裂的1,000米水平露天露天度，水平井1,000米，具有多个横向骨折。未裂缝的水平透露场景需要生命周期井筒稳定性评估。断裂水平井场景需要优化横向骨折及其间距。生产限制包括600psi管道压力，最大的油流量为5,000 bbl / d，最大5年的生产期，优先于更加加速恢复。该综合计划的结果使得了解了各种井压缩方案对基于技术和经济问题的决策的影响。研究中学到的经验教训可以是目标领域和其他类似领域的最佳开发的指南。

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