Conglomerate oil saturation measuring device and method

Abstract

The invention discloses a conglomerate oil saturation measuring device and method. The measuring device comprises a rock core holder system, a fluid injection system, a nuclear magnetic resonance system and a fluid collection system. Epoxy resin embedding treatment is carried out on a conglomerate sample which is easy to loosen and fall off in a measuring process; and a high-temperature and high-pressure displacement and nuclear magnetic resonance combined measurement device is used for in-situ measurement of the original oil saturation of a sample under a formation pressure condition, problems of fracturing fluid invasion, fluid loss, conglomerate grain falling, cracking and the like in the measurement process of a conventional method are solved, and technical support is provided for conglomerate reservoir research and resource quantity evaluation.

Description

Technical field [0001] The invention relates to the technical field of core experiments, in particular to a device and method for measuring conglomerate oil saturation. Background technique [0002] As an important type of oil and gas reservoirs in China, conglomerate is the object of research by geologists, especially in the recent period, accompanied by the large-scale conglomerate oil field in the Huanmahu area of ​​the Junggar Basin and the large-scale conglomerate reserve area in the north slope of the Dongying Sag in the Bohai Bay Basin. Discovery (Bi Yiquan. Genesis model and accumulation law of glutenite on the south slope of Binxian uplift, Dongying Sag[J].Journal of the University of Petroleum (Edition of Natural Science), 2002, 26(4): 12-17; Xie Fengmeng, Wu Fadong, Chen Jianyu, et al. Spatial distribution and accumulation of glutenite fans in Binnan Oilfield, Bohai Bay Basin[J].Petroleum Geology & Experiment, 2002, 24(4): 334-339; Kuang Lichun, Tang Yong, Lei Dewen, ...

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Problems solved by technology

[0008] 1) The experimental results cannot reflect the oil saturation of the sample under the original underground conditions. The entire oil washing process is completed under laboratory conditions without setting the underground temperature and pressure, so it reflects the current situation of residual hydrocarbons in the sample;

[0009] 2) The experimental results cannot eliminate the influence of fluid loss during the coring process and the sample placement process. Due to the high cost of pressure-holding and sealed coring, the mainstream coring method is conventional coring. During the entire coring process, due to drilling The intrusion of liquid will affect the saturation of the sample, and at the same time, due to the decrease of temperature and pressure, it will cause the rapid loss of fluid; it usually takes a long time for the core to be taken out to the laboratory, which will also cause the loss of fluid;

[0010] 3) Since conglomerate is prone to grain loss and cracking, the plunger sample is often damaged due to the displacement of temperature and fluid during the oil washing process by distillation, resulting in core rupture, which directly affects the subsequent measurement of pore volume, resulting in Inaccuracy of final oil saturation determination results

[0016] 1) Technology 2 is not suitable for conglomerate reservoirs that are prone to loosening and particle loss. If the conglomerate reservoir cannot be effectively treated in the early stage, particle loss and damage will easily occur during high temperature and high pressure displacement, and pipelines will be blocked, resulting in Experiment failed;

[0017] 2) The experimental results lack other data constraints, and cannot confirm the extent of the displacement process in the core

[0018] The above methods are all affected by the looseness of conglomerate, easy grain loss, cracking, etc., and cannot reflect the oil saturation of samples under the original underground conditions.

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