中东海上稠油油藏组份随深度变化的非等温组份模拟研究

H. Salimi, Bram Sieders, J. Rostami
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引用次数: 1

摘要

本研究的目的是为中东海上稠油油藏寻找最佳的提高采收率策略,该油藏的储层流体性质随深度变化,采用非等温成分模拟来模拟流体成分随深度的变化。观察到的成分变化是这样的:油密度从顶部的20°API变化到深层的11°API,活油粘度从顶部的14 cP增加到深层的449 cP。由于热力学平衡的概念不适用于具有组分变化的储层,因此我们使用不可逆热力学理论建立了一个组分PVT模型,该模型可以捕获观察到的组分和油性随深度的变化。接下来,根据CO2、油气膨胀和MMP测试对PVT模型进行了调整。随后,我们开发了一个使用单一组分PVT模型的组分储层动态模型,该模型可以模拟石油中CO2/油气的混相程度。然后,我们进行了动态IOR/EOR筛选,包括注水、油气注入、二氧化碳注入、水-CO2交替注入、聚合物注入、聚合物-CO2交替注入(PAG-CO2)和聚合物-CO2同时注入(SPCO2)。同时注入聚合物和CO2时,在顶部注入聚合物,在底部注入CO2。详细阐述了这些场景的仿真运行情况。所开发的成分PVT模型成功地再现了观测到的流体性质和成分随深度的变化。通过这种方法,计算出的流体性质随深度的变化是连续的,因为单个PVT区域只有一个PVT模型。对比了不同提高采收率方案的性能。模拟的增量采收率依次为注水、注油气、注WAG-CO2、注CO2、注聚合物(22 cP)、注PAG-CO2、注SPCO2。CO2-聚合物复合方案的增量采收率较高的原因是,宏观波及(聚合物)和微观驱油效率(CO2和聚合物)都保持较高。虽然CO2注入压力低于MMP,但冷凝气和汽化气驱动对剩余油饱和度非常有效(< 0.10)。SPCO2注入的另一个优点是,注入的流体能够很好地接触和扫过中、深层地层。在峰值规模下,二氧化碳-聚合物复合方案可将无为采收率提高85-119%。
本文章由计算机程序翻译,如有差异,请以英文原文为准。
Non-Isothermal Compositional Simulation Study for Determining an Optimum EOR Strategy for a Middle-East Offshore Heavy-Oil Reservoir with Compositional Variations with Depth
The objective of this study was to find an optimum EOR strategy for a Middle-East offshore heavy-oil reservoir that exhibits reservoir-fluids-properties variations with depth using non-isothermal compositional simulations that honor the fluids-compositional variations with depth. The observed compositional variations are such that the oil density changes from 20 °API in the crest to 11 °API in the deep part and the live-oil viscosity increases from 14 cP in the crest part to 449 cP in the deep part of the reservoir. Because the concept of thermodynamic equilibrium is not valid for the reservoir with compositional variations, we used the theory of irreversible thermodynamics to develop a compositional PVT model that captures the observed compositional and oil-properties variations with depth. Next, the PVT model was tuned against CO2 and hydrocarbon-gas swelling and MMP tests. Subsequently, we developed a compositional reservoir dynamic model that uses the single compositional PVT model and can simulate the degree of CO2/hydrocarbon-gas miscibility in oil. Then, we performed a dynamic IOR/EOR screening that includes water injection, hydrocarbon-gas injection, CO2 injection, water-alternating-CO2 injection, polymer injection, polymer-alternating-CO2 injection (PAG-CO2), and simultaneous polymer and CO2 injection (SPCO2). For simultaneous polymer and CO2 injection, polymer was injected at the top while CO2 was injected at the bottom. The simulation runs of these scenarios were elucidated in detail. The developed compositional PVT model successfully reproduces the observed fluids-properties and compositional variations with depth. In this way, the calculated fluids properties are continuous with depth because there is only a single PVT model for a single PVT region. The performances of different EOR scenarios were compared with each other. The simulated incremental oil recovery increases in the sequence of water injection, hydrocarbon-gas injection, WAG-CO2 injection, CO2 injection, polymer (22 cP) injection, PAG-CO2, and SPCO2. The reason for higher incremental recoveries with combined CO2-polymer scenarios is that both the macroscopic sweep (with polymer) and microscopic displacement efficiency (with CO2 and polymer) remain high. Although the CO2 injection pressure is lower than the MMP, the condensing- and vaporizing-gas drives are very efficient to the remaining oil saturation to low values (< 0.10). The other advantage of SPCO2 injection is that the intermediate and deep layers are well contacted and swept by the injected fluids. At the crest scale, combined CO2-polymer scenarios can increase the do-nothing recovery by 85–119%.
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