马来西亚沙捞越X区块PVT综合数据回顾、流体表征和分组研究

Lionel Kallang Laing, Seiji Shirai, K. Rosli, Oluwole A. Talabi, Nurul Suhaila Mohammad Fawzi
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引用次数: 0

摘要

Sarawak海上区块X由堆叠和多层储层组成,这些储层生产天然气、凝析油和石油,其中许多井的生产是混合的。在勘探和初始生产阶段,从每个储层采集并分析了47个地面PVT样品。尽管已经进行了大量的样品和一系列的PVT研究,但x区块的流体PVT及其油藏建模应用仍然是一个不确定因素。因此,我们进行了一项全面的3阶段PVT研究,并将其改进的结果应用于即将到来的模拟模型中,不仅可以代表每个储层内部的流体相互作用,还可以代表不同储层之间的流体相互作用。首先,使用Paredes等人(2014)提出的系统流程对每个样本进行详细的质量检查和验证,以确定高质量的样本。根据其流体样品质量指数(FSQI)对样品进行排序,并将最佳样品进行进一步分析。通过绘制所选样品的观察到的饱和压力、成分、CGR和其他关键变量与深度的关系,进行初始PVT分组分析。对现有的PVT模型和成分表征进行了回顾,发现除了液体饱和度的匹配质量之外,它们都是令人满意的,然后使用成分梯度实验生成预测剖面趋势,并与数据进行比较,以定义可以组合在一起的PVT数据。接下来,对每个PVT组进行状态方程(EOS)参数的建模和校准,以匹配实验室实验中观察到的特性,使用每组中由其FQSI值确定的最佳样本。新的PVT校准结果表明,与现有模型相比,PVT模型与实验室观测值之间的差异在饱和压力的0.1 -2.2%和CGR的0.5 - 17.8%之间有所改善。这表明得到了合理的组PVT模型。尽管如此,其中一组PVT的不确定性仍然很高,因为即使样品的FQSI很好,但由于观察到的油气接触(GOC)与观察到的饱和压力之间存在很大的不一致,因此需要对其流体进行调整。最后,利用现有的动态仿真模型,在接近原始采样条件下初始化PVT模型,并应用成分梯度对模型进行验证。与以前的模型相比,与样品和早期生产数据相比,改进了3 - 58%。对于进行流体调整的储层或PVT组来说,由于进一步校准的产量有限,仍然存在很大的不确定性。此外,由于油田寿命期间分离器条件的变化以及混合生产对井层贡献的不确定性,现有模型的动态历史匹配并没有立即反映出改进。这些都是今后工作的重点。
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Comprehensive PVT Data Review, Fluid Characterization and Grouping Study for Block X in Sarawak, Malaysia
Block X of offshore Sarawak consists of stacked and multi-layer reservoirs that produce gas, condensate and oil where the production is in-commingle from many wells. 47 surface PVT samples were taken and analyzed from every reservoir during the exploration and initial production periods. Despite the number of samples and a series of PVT studies had been conducted, fluid PVT and its reservoir modelling application remain an uncertainty for Block X. Therefore, a comprehensive 3-phase PVT study was conducted, and its improved results will be implemented in the upcoming simulation model to represent fluid interactions not only within each reservoir but also between different reservoirs that are produced in commingle. Firstly, a detailed quality check and validation were performed on every sample using a systematic process proposed in Paredes et al. (2014) to identify high-quality samples. These samples were ranked based on their Fluid Sample Quality index (FSQI), and the best samples were carried forward for further analysis. Initial PVT grouping analysis was performed by plotting observed saturation pressure, composition, CGR and other key variables versus depth for the selected samples. The existing PVT models and compositional characterization, which were reviewed and found to be satisfactory except for the matching quality of liquid saturation, were used to generate predicted profile trends using Compositional gradient experiments and compared to the data to define the PVT data that could be grouped together. Next, modelling and calibration of Equation of State (EOS) parameters to match the observed properties from lab experiments were performed for each PVT group using the best sample from each group as identified by its FQSI value. The results of the new PVT calibrations showed improvements over the existing models with the variance between the group PVT model and lab observations ranging from 0.1 -2.2% in saturation pressure and 0.5 – 17.8 % in CGR. This indicated that reasonable group PVT models had been obtained. Despite, uncertainty for one of the PVT groups remained high as its fluid needed to be adjusted due to a large inconsistency between the observed gas-oil-contact (GOC) and the observed saturation pressure even when its sample's FQSI was good. Finally, the new PVT models were validated with the existing dynamic simulation models by initializing them close to the original sampling conditions and applying a compositional gradient. Comparisons with previous models show improvements between 3 − 58% when compared to the sample and early production data. Significant uncertainty remains for the reservoir or PVT group where the fluid adjustment was performed due to its limited production for further calibration. In addition, improvements were not immediately reflected in the dynamic history match of the existing models because of the variation in separator conditions during field life and the uncertainty of wells’ zonal contributions from commingled production; these are aspects for future work.
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