缝洞型油藏凝胶-无机颗粒协同筑坝控水增油方法研究

doi:10.13809/j.cnki.cn32-1825/te.2024484

Abstract

Abstract:

To address the challenge of rapid bottom water breakthrough along fractures during water injection in fracture-cavity reservoirs, which makes “attic oil” difficult to recover effectively, a strategy of “gel-inorganic particle synergy damming for water control and oil enhancement” was proposed. The method constructed a stable dam with specific height and slope in near-wellbore cavities through the synergistic effects of gel plugging of channeling paths and vertical stacking of inorganic particles, raising the overflow point to divert bottom water, thereby expanding the water flooding sweep volume and mobilizing the remaining oil at the top. Based on field well cases and actual geological models, a large-scale visual physical model of fracture-cavity reservoir was established. Equivalent plugging agents and injection-production parameters were designed using similarity principles to simulate the in-reservoir damming process. The migration and distribution patterns of plugging agents under different injection modes were investigated, and the effects of plugging agent combination, slug number, total agent volume, agent ratio, injection rate, and cavity filling degree on dam morphology and performance of water control and oil enhancement were analyzed. Finally, based on back propagation (BP) neural network, a model was established to predict damming height and performance of enhanced oil recovery (EOR). The experimental results demonstrated that: (1) the gel-inorganic particle synergistic damming could effectively mobilize the top remaining oil in cavities, increasing recovery by 14.4% with significant water control and oil enhancement performance. (2) Plugging agent combinations directly determined dam morphology and height, while injection parameters significantly influenced the migration patterns of plugging agents, thereby affecting the performance of water control and oil enhancement. (3) After sufficient training, the BP neural network-based model successfully predicted dam height and EOR under different injection modes, with root mean square errors of 22.24 and 2.92, respectively. The study reveals the mechanisms of synergistic damming, clarifies directions for process parameter optimization, and provides new insights and effective methods for enhancing oil recovery in the later stages of water injection in fracture-cavity reservoirs.

Key words: fracture-cavity reservoir, attic oil, damming for water control and oil enhancement, gel, inorganic particles, enhanced oil recovery

CLC Number:

TE344

ZHANG Zhibo,WANG Dianlin,ZHANG Wen, et al. Research on gel-inorganic particle synergistic damming method for water control and oil enhancement in fracture-cavity reservoirs[J]. Petroleum Reservoir Evaluation and Development, 2026, 16(1): 174-185.

Figures/Tables 20

Fig.1

Fig.2

Fig.3

Table 1

Fig.4

Table 2

Equivalent experimental parameters"

相似准数	物理意义	相似性
$p ρ g L$	驱替压差与重力之比	动力相似
$μ ρ v L$	雷诺数	动力相似
$Q t (φ f + φ v) ρ L 3$	注入量与缝洞总体积之比	运动相似

Table 2

Table 3

Table 4

Fig.5

Table 5

Table 6

Fig.6

Fig.7

Fig.8

Fig.9

Fig.10

Fig.11

Table7

Fig.12

Fig.13

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分类	密度/（g/cm³）	黏度（温度25 ℃）/（mPa·s）	静态成胶时间/h	成胶强度	固相质量分数/%
现场凝胶	1.14	500	1~3（温度130 ℃）	H级
实验室凝胶	1.10	506	4~6（温度40 ℃）	H级
现场无机堵剂	1.14	30~35			20
实验室无机颗粒	1.16	60			20

参数	注采压差/MPa	原油密度/（g/cm³）	凝胶密度/（g/cm³）	无机颗粒密度/（g/cm³）	模型尺寸/m	凝胶黏度/（mPa·s）	无机颗粒黏度/（mPa·s）	注入速度/（mL/min）	孔隙度/%
实际油藏参数	2.00~20.00	0.8~1.0	1.14	1.14	200.0~600.0	500	30~35	30 000~60 000	3.0~20.0
物理模型参数	0.01~0.10	0.9	1.10	1.16	0.3~0.4	506	60	0.78~1.30	2.0~3.0

实验方案	研究内容	研究参数	固定参数
1	堵剂组合模式	单一凝胶堵剂	凝胶黏度500 mPa·s，密度1.14 g/cm³，无机颗粒黏度60 mPa·s，密度1.16 g/cm³
2		单一无机颗粒堵剂
3		凝胶+无机颗粒组合
4	段塞数量	二段塞	填充度60%，堵剂总量0.2 PV，注入速度0.8 cm³/min，凝胶与无机颗粒比为1∶2
5		三段塞
6		四段塞
7	堵剂总量	0.1 PV	填充度60%，二段塞，注入速度0.8 cm³/min，凝胶与无机颗粒比为1∶2
8		0.2 PV
9		0.3 PV
10		0.4 PV
11	堵剂比例	凝胶与无机颗粒比1∶2	填充度60%，堵剂总量0.2 PV，二段塞，注入速度0.8 cm³/min
12		凝胶与无机颗粒比1∶6
13		凝胶与无机颗粒比1∶10
14	注入速度	0.8 cm³/min	填充度60%，堵剂总量0.2 PV，二段塞，凝胶与无机颗粒比为1∶2
15		1.0 cm³/min
16		1.2 cm³/min
17	溶洞填充程度	未填充	堵剂总量0.2 PV，二段塞，注入速度0.8 cm³/min，凝胶与无机颗粒比为1∶2
18		填充度30%
19		填充度60%

实验方案	研究内容	研究参数	坝体高度/mm	提高采收率/%
1	堵剂组合模式	单一凝胶堵剂	52.9	0.8
2		单一无机颗粒堵剂	20.4	3.2
3		凝胶+无机颗粒组合	36.6	14.4
4	段塞数量	二段塞	58.5	14.4
5		三段塞	57.0	11.1
6		四段塞	53.3	10.3
7	堵剂总量	0.1 PV	49.0	4.0
8		0.2 PV	58.5	14.4
9		0.3 PV	59.5	16.1
10		0.4 PV	63.7	13.2
11	堵剂比例	凝胶与无机颗粒比为1∶2	58.5	14.4
12		凝胶与无机颗粒比为1∶6	56.8	6.4
13		凝胶与无机颗粒比为1∶10	56.2	5.8
14	注入速度	0.8 cm³/min	69.1	11.0
15		1.0 cm³/min	61.0	5.6
16		1.2 cm³/min	69.5	9.3
17	溶洞填充程度	无填充	47.0	15.5
18		填充度30%	36.6	12.5
19		填充度60%	53.3	14.4

模型参数	寻优范围	最优值
隐藏层1神经元个数	32	32
	48
	64
	96
	128
隐藏层2神经元个数	16	16
	24
	32
	48
	64
学习率	0.000 5	0.01
	0.001 0
	0.002 0
	0.005 0
	0.010 0
批量大小	16	16
	32
	48
	64
	128
训练轮数	500	1 000
	1 000
	2 000
	5 000

Research on gel-inorganic particle synergistic damming method for water control and oil enhancement in fracture-cavity reservoirs

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