裂缝性低渗油藏复合体系协同驱油适应性研究

doi:10.3969/j.issn.1001-1803.2022.03.003

Abstract

Abstract:

In the low-permeability reservoir, injection water is easy to flow along the high-permeability strips after simply profile control on the micro-fractures, which induces severe problems in the reservoir development. In this work, the foaming and stabilizing performance of a foam system and the gelling properties of a modified starch gel were evaluated. Then, the microadjustment and flooding of the foam and the collaborative oil displacement experiment of this compound system with fractured low-permeability core were carried out. The adaptability of collaborative oil displacement was verified with radial flow model, and the actual reservoir pattern was simulated. The experimental results show that the optimal mass concentrations of foaming agent and foam stabilizer are 0.5% and 0.1%, respectively. The strength and breakthrough pressure of starch gel system is high. After foam injection, the micro oil displacement efficiency of small pores during further water flooding is 14.21% higher than that of previous water flooding. And when the permeability ratio is approximately 30, its profile control performance is better. In the process of water flooding in fractured low-permeability reservoir, the collaborative oil displacement efficiency of modified starch gel combined with foam is best, which can increase the recovery by 22.17% and 46.07% as respectively compared with that of single use of modified starch gel or foam system. Moreover, the radial flow model validation experiment shows that the adaptability of this method is good in fractured low-permeability reservoir.

Key words: fracture, low permeability reservoir, foam, modified starch gel

CLC Number:

TQ423

Yue Wencheng,Fan Peng,Wang Kai,Zhao Hui,Liu An,Yang Hong. Adaptability study on a compound system for cooperative oil displacement in fractured low-permeability reservoir[J].China Surfactant Detergent & Cosmetics, 2022, 52(3): 245-252.

Figures/Tables 10

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References 21

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矿化度/（mg/L）								pH	水型
Cl^-	HCO₃^-	Na⁺	K⁺	Mg²⁺	Ca²⁺	Ba²⁺	Fe²⁺	pH	水型
32 235	93	13 155	1 847	361	20 845	722	45	6.9	CaCl₂

实验编号		孔隙度/%	渗透率/（10^-3μm²）	渗透率级差	有无裂缝	注入段塞
1	A	15.27	3.18	10	无	地层水+0.4 PV泡沫+地层水
	A	16.47	30.26	10	无	地层水+0.4 PV泡沫+地层水
	B	15.19	3.09	30	有	地层水+0.4 PV泡沫+地层水
	B	16.15	89.58	30	有	地层水+0.4 PV泡沫+地层水
	C	14.89	2.96	30	无	地层水+0.4 PV泡沫+地层水
	C	17.68	83.27	30	无	地层水+0.4 PV泡沫+地层水
	D	14.97	3.25	50	无	地层水+0.4 PV泡沫+地层水
	D	19.02	163.18	50	无	地层水+0.4 PV泡沫+地层水
2	A	15.64	3.09	30	有	地层水+0.2 PV凝胶+地层水
	A	18.02	89.15	30	有	地层水+0.2 PV凝胶+地层水
	B	15.31	2.89	30	有	地层水+0.2 PV凝胶+地层水+0.4 PV泡沫+地层水
	B	17.68	91.39	30	有	地层水+0.2 PV凝胶+地层水+0.4 PV泡沫+地层水
	C	14.69	3.34	50	有	地层水+0.2 PV凝胶+地层水+0.4 PV泡沫+地层水
	C	19.18	170.18	50	有	地层水+0.2 PV凝胶+地层水+0.4 PV泡沫+地层水

ρ（MnCl₂）/（mg/L）	泡沫体系（0.5%起泡剂+0.1%稳泡剂）		改性淀粉凝胶
ρ（MnCl₂）/（mg/L）	起泡体积/mL	半衰期/s	弹性模量/Pa	损耗模量/Pa	突破压力/MPa
0	653	995	565	44	6.7
15 000	655	994	563	45	6.7

实验编号		水驱采收率/%	采收率提高幅度/%
实验编号		水驱采收率/%	改性淀粉凝胶+水驱	泡沫+水驱	累计
1	A	21.23	—	26.28	26.28
	B	0.68	—	1.75	1.75
	C	19.31	—	29.19	29.19
	D	17.54	—	10.89	10.89
2	A	0.65	25.65	—	25.65
	B	0.71	27.14	20.68	47.82
	C	0.67	18.74	12.23	30.97

Adaptability study on a compound system for cooperative oil displacement in fractured low-permeability reservoir

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