Characterization and Application of Original and Developed Flow Units in Tight Oil Reservoirs

doi:10.7657/XJPG20260213

Abstract

Abstract:

Current research on reservoir flow units often neglects the flow unit transformation caused by development engineering factors, resulting in flow unit classification that do not match the actual development status of oilfields. To provide a flow unit classification more in line with the distribution of artificial fractures after perforation and fracturing, this paper takes the Chang 8 tight oil reservoir in the Fuxian area of the Ordos Basin as an example for investigation. Based on selected parameters (5 static parameters and 2 dynamic parameters), the Chang 8 tight oil reservoir was categorized into 4 classes of original flow units and developed flow units through cluster analysis. Combining discriminant analysis with microscopic pore structure, the classification was verified. Finally, the distribution of original and developed flow units was characterized, and the application of the flow units to reservoir development was clarified. The results show that original flow units are controlled by sedimentary microfacies, while developed flow units are controlled by engineering factors such as perforation thickness, proppant injection intensity, and water injection rate. After reservoir fracturing, the remaining oil zone gradually shifts towards lower-level flow units. Class A and B developed flow units should be developed by controlling injection pressure and optimizing perforation horizons. Re-fracturing or augmented injection should be conducted to improve development efficiency for Class C and D developed flow units.

Key words: Ordos Basin, tight oil reservoir, Chang 8 reservoir, flow unit, 3D model, remaining oil

CLC Number:

TE122.1

ZHU Rongxing, QU Hongjun, YIN Hu, SU Shuai, YANG Xiaofeng. Characterization and Application of Original and Developed Flow Units in Tight Oil Reservoirs[J]. Xinjiang Petroleum Geology, 2026, 47(2): 241-252.

Figures/Tables 13

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参数	数值	参数	数值
原始地层压力/MPa	11.3	原始气油比/（m³·t^-1）	54.08
饱和压力/MPa	5.494	原油体积系数	1.22
地层原油密度/（g·cm^-3）	0.824	原油压缩系数/（MPa^-1）	8.9×10^-4
地层原油黏度/（mPa·s）	0.954	地层温度/℃	53.8
束缚水饱和度/%	42.22	残余油饱和度/%	17.45

原始流动单元分类	有效厚度/m	孔隙度/%	渗透率/mD	储集层品质因子	含油饱和度/%
A类	0.99~15.59 （4.17）	12.60~14.46 （13.37）	0.15~0.91 （0.43）	0.11~0.26 （0.17）	33.56~58.43 （45.52）
B类	0.50~14.18 （3.59）	10.90~12.10 （11.45）	0.10~1.01 （0.29）	0.06~0.30 （0.14）	27.53~49.37 （35.73）
C类	0.80~12.62 （3.41）	9.20~10.62 （10.05）	0.03~0.44 （0.16）	0.07~0.21 （0.12）	8.03~47.80 （27.43）
D类	0.46~9.87 （2.79）	6.90~8.70 （7.96）	0.10~0.14 （0.12）	0.11~0.14 （0.12）	1.03~42.30 （19.99）

开发后流动单元分类	有效厚度/m	孔隙度/%	渗透率/mD	储集层品质因子	含油饱和度/ %	初始产液量/ （m³·d^-1）	加砂强度/ （m³·m^-1）
A类	1.09~15.83 （5.50）	5.11~13.99 （11.03）	0.18~0.56 （0.40）	0.120~0.350 （0.190）	18.66~47.60 （31.16）	0.33~9.19 （3.53）	5.56~35.00 （11.69）
B类	0.89~12.62 （4.40）	6.75~13.78 （10.65）	0.21~0.49 （0.38）	0.120~0.260 （0.188）	16.00~47.80 （28.76）	0.12~4.91 （1.87）	4.00~15.00 （7.23）
C类	0.89~8.87 （3.60）	5.60~15.20 （9.52）	0.19~0.54 （0.34）	0.120~0.190 （0.188）	7.74~38.70 （25.78）	0.09~3.28 （0.88）	4.17~15.00 （7.21）
D类	0.79~6.94 （3.28）	4.23~12.03 （9.15）	0.15~0.45 （0.32）	0.120~0.190 （0.185）	15.21~35.47 （18.82）	0.04~3.98 （0.69）	2.61~8.00 （4.46）