Quantitative Characterization of Numerical Simulation of

doi:10.12422/j.issn.1672-6952.2023.04.011

Abstract

Abstract:

In order to optimize the effect of Bohai oilfield regulation and flooding in B water injection development, the numerical simulation software of CMG reservoir was used to carry out optimization research on the effect of "weak gel+water?based microspheres" combined displacement to improve recovery,and according to the known geological reservoir properties of the oilfield,the actual three?dimensional geological model was established,and the historical fitting was carried out in combination with the previous production history.The factors affecting the modulation effect of single section of plugged weak gel modulation,single section of water?based microsphere modulation and driving and the factors affecting the modulation effect of "weak gel+water?based microspheres" were analyzed and optimized,and the related production indexes were predicted.The results show that the combined modulation effect of "weak gel+water?based microspheres" is significantly better than that of a single segment of plug modulation and driving.The optimal injection process parameters of the modulated blocking agent (weak gel) were selected through numerical simulation:the injection mass fraction is 0.50% crosslinker,the injection amount is 0.000 11 PV,the injection speed of A2H well is 240 m³/d,and the injection speed of A3H well is 200 m³/d.The optimal injection process parameters of the modulator (water?based microspheres) were selected through numerical simulation: the injection mass fraction is 0.30%,the injection amount is optimally 0.003 00 PV,and the injection speed of A2H and A3H wells is about 500~600 m³/d. This design scheme can effectively achieve the purpose of increasing precipitation and oil recovery.

Key words: Combinatorial modulation drive, Numerical simulation, Injection parameter optimization, Increased recovery, Scheme design

摘要：

为优化渤海B油田注水开发油田调驱效果，利用CMG数值模拟软件，围绕“弱凝胶+水基微球”组合调驱提高采收率效果展开了优化研究。根据该油田已知的地质油藏属性，对生产井的历史数据进行历史拟合，建立了实际三维地质模型，对影响单一段塞弱凝胶调驱、单一段塞水基微球调驱以及“弱凝胶+水基微球”组合调驱效果的因素进行分析优化设计，并针对相关生产指标进行了预测。结果表明，“弱凝胶+水基微球”组合调驱效果明显优于单一段塞调驱效果；通过数值模拟优选出调剖剂（弱凝胶）最佳注入工艺参数：质量分数为0.50%，注入量为0.000 11 PV，A2H井、A3H井注入速度分别为240、200 $m 3 / d$ ；通过数值模拟优选出调驱剂（水基微球）最佳注入工艺参数：质量分数为0.30%，注入量为0.003 00 PV，A2H井、A3H井注入速度均为500~600 $m 3 / d$ 。组合调驱方案能有效达到降水增油和提高原油采收率的目的。

关键词: 组合调驱, 数值模拟, 注入参数优化, 提高采收率, 方案设计

CLC Number:

TE357

Zhen Zhou, Yunbao Zhang, Chengzhou Wang, Zhaohai Zhan, Xulin Zheng, Danfeng Chen. Quantitative Characterization of Numerical Simulation of "Weak Gel+Water⁃Based Microspheres" Combined Modulation[J]. Journal of Liaoning Petrochemical University, 2023, 43(4): 72-77.

周振, 张云宝, 王承州, 詹兆海, 郑旭林, 陈丹丰. “弱凝胶+水基微球”组合调驱数值模拟量化的表征研究[J]. 辽宁石油化工大学学报, 2023, 43(4): 72-77.

Figures/Tables 9

方案	w（弱凝胶）/%	累计产油量/m³	增油量/m³	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
空白水驱		648 011.93		21.23		90.06
1	0.20	650 589.81	2 577.88	21.32	0.09	89.69	0.37
2	0.30	651 062.00	3 050.07	21.34	0.11	89.62	0.44
3	0.40	652 062.81	4 050.88	21.37	0.14	89.53	0.53
4	0.50	653 072.94	5 061.01	21.40	0.17	89.45	0.61
5	0.60	653 595.88	5 583.95	21.42	0.19	89.39	0.67

方案	注入量/PV	累计产油量/m³	增油量/m³	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
空白水驱		648 011.93		21.23		90.06
1	0.000 10	650 744.44	2 732.51	21.32	0.09	89.70	0.36
2	0.000 11	652 487.56	4 475.63	21.38	0.15	89.51	0.55
3	0.000 12	652 992.63	4 980.70	21.40	0.17	89.47	0.59
4	0.000 13	653 439.44	5 427.51	21.41	0.18	89.41	0.65
5	0.000 14	654 104.69	6 092.76	21.43	0.20	89.37	0.69

方案	注入速度/(m³ $⋅$ d^-1)		累计产油量/m³	增油量/m³	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
方案	A2H井	A3H井	累计产油量/m³	增油量/m³	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
空白水驱			648 011.93		21.23		90.06
1	200	200	652 487.56	4 475.63	21.39	0.16	89.51	0.55
2	200	235	651 857.19	3 845.26	21.38	0.15	89.58	0.48
3	235	200	652 937.19	4 925.26	21.36	0.13	89.48	0.58
4	235	235	650 965.50	2 953.57	21.33	0.10	89.66	0.40

方案	注入速度/(m³ $⋅$ d^-1)		累计产油量/m³	增油量/m³	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
方案	A2H井	A3H井	累计产油量/m³	增油量/m³	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
空白水驱			648 011.93		21.23		90.06
1	200	200	652 487.56	4 475.63	21.39	0.16	89.51	0.55
2	200	235	651 857.19	3 845.26	21.38	0.15	89.58	0.48
3	235	200	652 937.19	4 925.26	21.36	0.13	89.48	0.58
4	235	235	650 965.50	2 953.57	21.33	0.10	89.66	0.40

方案	w（水基微球）/%	累计产油量/m³	增油量/m³	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
空白水驱		648 011.93		21.23		90.06
1	0.10	649 385.56	1 373.63	21.28	0.05	89.85	0.21
2	0.20	650 003.25	1 991.32	21.30	0.07	89.79	0.27
3	0.30	650 489.94	2 478.01	21.32	0.09	89.75	0.31
4	0.40	650 950.88	2 938.95	21.33	0.10	89.67	0.39
5	0.50	651 665.44	3 653.51	21.35	0.12	89.59	0.47

方案	注入速度/(m³ $⋅$ d^-1)		累计产油量/m³	增油量/m³	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
方案	A2H井	A3H井	累计产油量/m³	增油量/m³	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
空白水驱			648 011.93		21.24		90.06
1	500	600	650 557.75	2 545.82	21.32	0.08	89.73	0.33
2	500	630	650 371.13	2 359.20	21.31	0.08	89.74	0.32
3	540	600	650 314.06	2 302.13	21.31	0.08	89.74	0.32
4	540	630	649 887.13	1 875.20	21.30	0.06	89.79	0.27
5	590	630	649 812.56	1 800.63	21.30	0.06	89.79	0.26

方案	注入速度/(m³ $⋅$ d^-1)		累计产油量/m³	增油量/m³	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
方案	A2H井	A3H井	累计产油量/m³	增油量/m³	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
空白水驱			648 011.93		21.24		90.06
1	500	600	650 557.75	2 545.82	21.32	0.08	89.73	0.33
2	500	630	650 371.13	2 359.20	21.31	0.08	89.74	0.32
3	540	600	650 314.06	2 302.13	21.31	0.08	89.74	0.32
4	540	630	649 887.13	1 875.20	21.30	0.06	89.79	0.27
5	590	630	649 812.56	1 800.63	21.30	0.06	89.79	0.26

方案	段塞类型	注入量/PV	注入速度/(m³ $⋅$ d^-1)		累计产油量%	增油量/%	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
方案	段塞类型	注入量/PV	A2H井	A3H井	累计产油量%	增油量/%	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
	空白水驱				648 011.93		21.24		90.06
	弱凝胶	0.000 11	240	200
1	水基微球	0.001 00	500	600	656 099.75	8 087.82	21.50	0.26	89.18	0.88
2		0.002 00	500	600	657 012.75	9 000.82	21.53	0.29	89.10	0.96
3		0.003 00	500	600	658 544.31	10 532.38	21.58	0.34	88.94	1.12
4		0.004 00	500	600	659 335.31	11 323.38	21.61	0.37	88.87	1.19
5		0.005 00	500	600	659 909.06	11 897.13	21.62	0.38	88.79	1.27

方案	段塞类型	注入量/PV	注入速度/(m³ $⋅$ d^-1)		累计产油量%	增油量/%	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
方案	段塞类型	注入量/PV	A2H井	A3H井	累计产油量%	增油量/%	采收率/%	采收率增幅/%	调驱后最低含水率/%	含水率降幅/%
	空白水驱				648 011.93		21.24		90.06
	弱凝胶	0.000 11	240	200
1	水基微球	0.001 00	500	600	656 099.75	8 087.82	21.50	0.26	89.18	0.88
2		0.002 00	500	600	657 012.75	9 000.82	21.53	0.29	89.10	0.96
3		0.003 00	500	600	658 544.31	10 532.38	21.58	0.34	88.94	1.12
4		0.004 00	500	600	659 335.31	11 323.38	21.61	0.37	88.87	1.19
5		0.005 00	500	600	659 909.06	11 897.13	21.62	0.38	88.79	1.27

层位	增油量/m³	层位	增油量/m³
1	3 525.00	8	218.00
2	2 767.00	9	-115.00
3	1 132.00	10	119.00
4	896.00	11	-168.00
5	1 948.00	12	-116.00
6	120.00	13	6.50
7	91.00	14	108.88

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