Reconstruction of the evolution of deep fluids in light oil reservoirs in the Central Tarim Basin by using PVT simulation and basin modeling. (September 2019)

• Record Type: Journal Article
• Authors: Chen, Chengsheng; Wang, Yunpeng; Beagle, Jamie R.; Liao, Lingling; Shi, Shuyong; Deng, Rui
• Is Part Of: Marine and petroleum geology. Volume 107(2019)
• Page Start: 116
• Page End: 126
• Publication Date: 2019-09
• Subjects: Fluid composition -- Basin modeling -- PVT simulation -- Light oil reservoirs -- Tarim Basin; Submarine geology -- Periodicals; Petroleum -- Geology -- Periodicals; Géologie sous-marine -- Périodiques; Pétrole -- Géologie -- Périodiques; Petroleum -- Geology; Submarine geology; Periodicals; Electronic journals; 551.468
• DOI: 10.1016/j.marpetgeo.2019.05.009
• Languages: English
• ISSNs: 0264-8172

Abstract

Abstract: To better understand the fluid phase state and its evolution in a deep environment, an integrated PVT simulation and basin modeling method for two light oil reservoirs in the Central Tarim Basin was proposed and applied. The fluid phase models were built using PVT simulation technology after successfully recovering the fluid compositions. The envelopes of fluid from either the Awatage Formation (Є2 a) for Well ZS1 or the Wusongar Formation (Є1 w) for Well ZS5 show the order from cricondenbar (Pm ), critical point (Cp ) to cricondentherm (Tm ), suggesting a single liquid phase for the present fluids in the Cambrian subsalt dolomite reservoirs. The result of this study indicates that the two reservoirs did not experience phase changes, phase differentiation, or oil cracking and maintained a universal state of the liquid phase over time by combining the evolutionary history of temperature and pressure derived from basin modeling. The fluid density and viscosity experienced relatively complicated fluctuation processes, and the fluctuations of fluid viscosity over geologic history are much more apparent than the variations in fluid density. The density and viscosity of the Awatage Formation (Є2 a) for Well ZS1 are found to be lower than those of the Wusongar Formation (Є1 w) for Well ZS5. The results reveal that factors, such as good trap conditions, a stable tectonic background, a low paleo-geothermal gradient (1.6–2.8 °C/100 m), and the weak effect of thermal sulfate reduction (TSR) altogether act on the early-accumulated light oil and gas that has been preserved as a single liquid phase over time. These results are significant for future explorations of large-scale liquid petroleum in Cambrian subsalt dolomite reservoirs of the Central Tarim Basin. Highlights: Deep fluid phase evolutions of light oil reservoirs in Central Tarim Basin were studied by integrating PVTsim and PetroMod. Deep fluid compositions of light oil reservoirs were recovered using PVTsim after constraints. Reservoir fluids did not show phase changing or differentiation throughout the geologic history. Fluid behavior is dominated by fluid viscosity rather than fluid density. Fluid density and viscosity of Well ZS1 are obviously lower than those of Well ZS5.