非均相驱油体系与低中渗油藏适应性评价研究

doi:10.13809/j.cnki.cn32-1825/te.2020.06.003

Abstract

Abstract:

Wang-17 Block of Wangji Oilfield is the first zone in China to carry out polymer flooding EOR test with multi-stage heterogeneous profile control slug in oil reservoirs with low-medium permeability. The objective is to form the matching technology of chemical flooding in small fault block and low-medium permeability reservoirs, and to lead, demonstrate and use the remaining Class I and Class II chemical flooding reserves of 3 512×10⁴ t in Henan Oilfield. The keys of the technology are adaptability of flooding agent to reservoir, effective plugging of extreme water-consuming layers and well pattern adjustment. Therefore, starting with the adaptability of polymer and preformed particle gel（PPG） to reservoir, the grain size distribution of PPG and the factors affecting water absorption and swelling of viscoelastic particulate have been studied and the salt resistance, shear resistance and thermal stability have been characterized. Meanwhile, the relation between particle number and concentration, the possibility of injection, the oil displacement efficiency and the diversion rate of heterogeneous system have been evaluated. The results show that the optimized heterogeneous flooding system has better adaptability to low-medium permeability reservoirs. Field application has achieved the effect of increasing oil production and reducing water, which provides technical support and significant reference to EOR in the similar oil reservoirs.

Key words: low-medium permeability reservoir, polymer flooding, preformed particle gel, heterogeneous flooding, adaptability

CLC Number:

TE357

Jun LU,Zhuo ZHANG,Lisheng YANG, et al. Adaptability of heterogeneous flooding system to low-medium permeability reservoirs[J]. Reservoir Evaluation and Development, 2020, 10(6): 17-23.

Figures/Tables 12

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References 19

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聚合物/ （mg·L^-1）	HNPPG-1/ （mg·L^-1）	沉降临界时间/h	聚合物/ （mg·L^-1）	HNPPG-1/ （mg·L^-1）	沉降临界时间/h
800	400	>24	800	750	>24
1 000	500	>24	1 000	750	>24
1 200	600	>24	1 200	750	>24
1 500	750	>24	1 500	750	>24
3 000	1 500	>24	3 000	750	>24
5 000	2 500	>24	5 000	750	>24

样品	浓度/ （mg·L^-1）	粒径/ μm	颗粒重量/g	黏度/ （mPa·s）	时间/ d	30 d保留率/%
样品	浓度/ （mg·L^-1）	粒径/ μm	颗粒重量/g	黏度/ （mPa·s）	时间/ d	粒径	颗粒重量	黏度
HNPPG -1	5 000	94	16.6	202.7	0	70.82	78.91	143.57
		394	16.7	236.4	6
		368	14.8	254.2	10
		330	14.2	268.1	20
		279	13.1	291.6	30

浓度/ （mg·L^-1）	搅拌速度/ rpm	黏度/（mPa·s）		过网重量/g		剪切时间/ min	10 min保留率/%
		初始	剪切	60目	100目		黏度	颗粒
		初始	剪切	60目	100目		黏度	过60目	过100目
3 000	12 000	170.1	170.1	3.74	4.43	0	84.3	92.2	71.3
		168.6	161.3	3.12	4.39	3
		170.7	153.4	3.69	3.41	6
		168.9	141.4	3.45	3.16	10
	300	170.9	165.8	3.72	4.37	0	97.6	96.5	94.3
		169.2	165.2	3.68	4.31	3
		170.2	165.6	3.64	4.26	6
		170.1	166.1	3.59	4.12	10

聚合物（P）∶PPG	聚合物/ （mg·L^-1）	PPG/ （mg·L^-1）	体系黏度/ （mPa·s）	弹性模量/mPa
5∶1	1 500	300	70.4	298
4∶1	1 500	375	72.3	376
3∶1	1 500	500	75.2	462
2∶1	1 500	750	110.0	591
3∶2	1 500	1 000	132.8	771
1∶1	1 500	1 500	184.3	1 090

注入体系配方	注入压力/MPa	渗透率/ μm²	孔隙度/ %	注入端阻力系数	残余阻力系数	封堵效率/ %
1 200 mg/L（P）+ 800 mg/L（HNPPG-1）	3.5	0.395	26.90	185.27	14.86	85.1
1 200 mg/L（P）+ 800 mg/L（HNPPG-1）	6.0	0.309	12.51	290.50	12.40	91.9
1 200 mg/L（P）+ 800 mg/L（HNPPG-1）	17.0	0.190	20.15	365.33	64.53	99.8
1 000 mg/L（P）+ 200 mg/L（HNPPG-1）	7.5	0.198	20.91	203.57	40.77	97.6

Adaptability of heterogeneous flooding system to low-medium permeability reservoirs

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非均相复合驱配方 0.6PV	空气渗透率/ μm²	水驱油采收率/%	水驱油分流率/%	化学驱分流率/%	后续水驱分流率/%	最终采收率/%	提高采收率/%
0.1PV（PPG/P）+0.4PV（P）+0.1PV（PPG/P）	0.204	31.03	3	30	2	55.13	24.10
	0.569	42.08	97	70	98	63.79	21.71
	并联岩心	36.96	100	100	100	59.77	22.81
0.1PV（PPG/P）+0.2PV（P）+0.05PV（PPG/P）+0.2PV（P）+0.05PV（PPG/P）	0.213	17.31	2	35~40	15	59.87	42.56
	0.654	39.44	98	60~65	85	63.01	23.57
	并联岩心	32.04	100	100	100	61.96	29.92

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