页岩油储层压裂液渗吸驱油机理研究

doi:10.13809/j.cnki.cn32-1825/te.2024.05.011

Abstract

Abstract:

The imbibition displacement of fracturing fluid is a key technique for enhancing oil recovery in shale oil reservoirs. This paper assesses the impact of fracturing fluid wetting modifiers on the efficiency of imbibition displacement and explores the underlying mechanisms at play in shale oil reservoirs. Tests were conducted on the surface tension, interfacial tension, and wettability of the treating agent, alongside investigations into its compatibility with conventional fracturing fluids. Additionally, the imbibition displacement efficiency of rock samples with varying pore sizes was evaluated. The results indicate that the anionic surfactant AOS proved to be the most effective treatment agent for improving the wetting properties of fracturing fluids. The imbibition displacement efficiencies observed were 8.17% for particles, 17.55% for matrix, and 37.37% for fractured rock samples. These findings demonstrate that the imbibition displacement force encompasses buoyancy, buoyancy-capillary, and capillary forces. By altering rock wettability, the modifier significantly enhances the capillary force, thus boosting oil displacement efficiency by approximately 152.9% compared to conventional fracturing fluids. The influence of pore structure on the dominant imbibition displacement force was also noted. Capillary forces were predominant in small pores, and buoyancy is the main force for natural and hydraulic fractures. The research on the imbibition displacement mechanism of fracturing fluid provides valuable guidance for the efficient development of tight shale oil reservoirs.

Key words: shale oil, imbibition displacement, wetting modification, pore structure, capillary force

CLC Number:

TE357

LIU Xugang,LI Guofeng,LI Lei, et al. Imbibition displacement mechanism of fracturing fluid in shale oil reservoir[J]. Petroleum Reservoir Evaluation and Development, 2024, 14(5): 756-763.

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References 21

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渗吸流体	黏度/（mPa·s）	界面张力/（mN/m）	接触角/（°）
处理剂改性压裂液体系	2.6	0.041	28.4
现用改性压裂液体系	2.7	0.062	32.1
常规滑溜水	3.1	0.650	41.8

处理剂种类	“气-水-固”三相接触角/（°）						平均值/（°）
处理剂种类	DA-31	DA-32	DA-33	DA-34	DA-35	DA-36	平均值/（°）
OA-14	23.2	31.3	23.2	24.9	22.4	20.1	24.18
CTAB	21.2	26.5	24.5	25.6	20.9	22.4	23.52
HSB1214	28.9	23.8	19.3	25.2	21.6	29.5	24.71
LHSB	40.9	41.3	36.8	29.5	22.9	24.2	32.60
AOS	9.4	15.4	8.8	6.7	13.0	15.3	11.40
现用改性剂	25.1	30.2	22.8	21.5	17.6	22.3	23.25
常规滑溜水	42.1	44.2	29.9	26.8	32.7	48.1	37.30

处理剂种类	实验条件	“油-水-固”三相接触角/（°）							平均值/（°）
处理剂种类	实验条件	DA-37		DA-38	DA-39		DA-40		平均值/（°）
OA-14	模拟油浸泡 48 h	63.2	84.1		70.8	88.5		75.15
CTAB		67.2	71.1		65.8	59.4		65.88
HSB1214		87.6	94.1		79.7	88.5		87.48
LHSB		72.9	88.2		95.0	92.4		87.13
AOS		50.8	71.4		55.7	72.2		60.53
现用改性剂		63.5		58.9	68.7		65.1		64.05
常规滑溜水		98.3		86.9	92.1		98.6		93.98

改性压裂液体系	配方	油水表面张力/（mN/m）	油水界面张力/（mN/m）
常规滑溜水	0.02%降阻剂+0.1%助排剂+0.1%破乳剂	25.1	0.650
现用改性压裂液体系	常规滑溜水+0.05%驱油剂+0.1%润湿反转剂	24.2	0.062
OA-14改性压裂液体系	常规滑溜水+0.1%OA-14	26.8	0.095
AOS改性压裂液体系	常规滑溜水+0.1%AOS	21.5	0.041
CTAB改性压裂液体系	常规滑溜水+0.05%CTAB	—	—

Imbibition displacement mechanism of fracturing fluid in shale oil reservoir

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