P. Liu

Sinopec (China)

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G. Zhang

K. Sepehrnoori

The University of Texas at Austin

Jinjun Xu

University of Jinan

Chunqing Jiang

Liaoning Technical University

Onyema Mark

Geological Survey of Canada

Z. Chen

Geological Survey of Canada

Xuan Ma

Chinese Academy of Medical Sciences & Peking Union Medical College

H. Zhang

China University of Petroleum, Beijing

Jianliang Wang

China University of Petroleum, Beijing

M. Li

Sinopec (China)

Cooperative Institutions

Sinopec (China)

China University of Petroleum, Beijing

Geological Survey of Canada

China Agricultural University

Tsinghua University

The University of Texas at Austin

University of Jinan

China University of Petroleum, East China

Schlumberger (British Virgin Islands)

State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation

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Combined Source and Maturity Influence on Molecular Tracers and Implications For Oil-Source Correlation in Deep Reservoirs

30th International Meeting on Organic Geochemistry (IMOG 2021) (2021)

Xuan Ma M. Li P. Liu Jinjun Xu Q. Chen

Summary In this study, geochemical characteristics of two Devonian oil families in Western Canada Sedimentary Basin (WCSB) will be used as an example, to demonstrate the source affected trends in thermal maturation of common biomarker compounds in crude oils. Our results suggest that deconvolution of the possible source and maturity effects is necessary to ensure the effective application of molecular tracers in oil-source correlation of the deep petroleum systems. Comparison of the molecular parameters for the three sample sets reveals several distinct compositional straits for the evaporate and carbonate sourced oils. The most important feature of the chemical composition and molecular distributions for these oils is the significant variation in the concentrations of sulfur containing compounds and the abundance of 17(H)-hopanes relative to other terpenoid components such as 8,14-secohopanes, C23 tricyclic terpane, C24 tetracyclic terpane, 18(H)-22,29,30-trisnorneohopane (Ts) and 18(H)-30-norneohopane (C29Ts). These oils form several continuums between the extreme end members of terpane and sterane distributions likley reflecting the inherited differences in source character, diagenetic change, and thermal cracking effects between the sulfate and iron-rich source rocks. Recognizing lithofacies signature and matrix effects is important for deep reservoired fluids, as it could signficantly increase the confidence of biomarker data interpretation.

Sterane

Energy source

10.3997/2214-4609.202134211

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A Novel Model of Foam Flooding Considering Multi-Factors for Enhancing Oil Recovery

Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles (2014)

Jianliang Wang Huiqing Liu H. Zhang G. Zhang P. Liu

Foam flooding is a promising technique for achieving mobility control and diverting fluid into low-permeability strata in post-water-flooding reservoirs. However, foam flow is very complicated and is influenced by many factors which have not been studied and explored very rigorously (i.e. permeability, surfactant concentration, foam quality, reservoir temperature, oil saturation, water saturation and seepage velocity). Based on core flooding experiments of foam flowing and blocking rules using two kinds of foaming agents, a novel model of foam flooding considering the influences of the above factors is established and solved using a reservoir simulator which is formulated using the IMPES method in conjunction with a Runge-Kutta method. Then, the validation is performed by core flooding experiments in both the absence and presence of oil. Finally, the simulator is used to investigate the effects of the permeability max-min ratio, ratio of vertical to horizontal permeability, gas-liquid ratio, depositional sequence, foaming agent concentration, and reservoir temperature.

Saturation (graph theory)

Foaming agent

Water flooding

10.2516/ogst/2014025

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Citations (6)