Lithologic Reservoirs ›› 2026, Vol. 38 ›› Issue (2): 178-193.doi: 10.12108/yxyqc.20260216

• PETROLEUM ENGINEERING AND OIL & GAS FIELD DEVELOPMENT • Previous Articles     Next Articles

Prediction method of water-to-gas gravity displacement efficiency and interface stability of high-dip angle reservoirs：A case study of Paleogene Shahejie Formation reservoir in Liuzan area of Bohai Bay Basin

XIONG Yu1(), ZHANG Weicen1(), LI Yamei1, GENG Wenshuang2, WU Daoming1, MU Dan1, LIU Tong1   

  1. 1 Faculty of Petroleum and Natural Gas Engineering, Southwest Petroleum University, Chengdu 610500, China
    2 Research Institute of Exploration and Development, PetroChina Jidong Oilfield Branch, Tangshan 063004, Hebei, China
  • Received:2025-07-29 Revised:2025-09-20 Online:2026-03-01 Published:2025-12-19

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Abstract:

By conducting nuclear magnetic resonance analysis and displacement experiments on core samples with different physical properties, the influence of formation dip angle and water cut on oil displacement efficiency in Es32+3 reservoir of Paleogene Shahejie Formation in Liuzan area of Bohai Bay Basin was explored, and a two-dimensional model focusing on injection-production parameters was established to reveal the key factors affecting gas-liquid interface stability and displacement efficiency. The results show that: （1） During the transition from water flooding to gas flooding in high-dip angle reservoirs of northern Liuzan area, the top gas injection technology improves oil displacement efficiency by 20% approximately，controlled by the stable gas cap formed by gravity differentiation and the immiscible displacement mechanism dominated by it, while the improvement of oil displacement efficiency by direct gravity is relatively limited. （2） Appropriately increasing the injection-production ratio can enhance gas cap pressure and the ability of gas to penetrate micro-pores, thereby improving gas-liquid interface stability. （3） The equation for stable gas injection rate can effectively predict the optimal range of gas injection rate for gravity drive，and can analyze the development dynamics of gas injection in real time.

Key words: water to gas drive, gravity, gas-fluid interface, gas injection rate, high-dip angle reservoir, Shahejie Formation, Paleogene, Liuzan area, Bohai Bay Basin

CLC Number: 

  • TE341

Fig. 1

Structural location of Es32+3 reservoir in northern Liuzan area (a， b) and comprehensive stratigraphic column of Paleogene (c)， Bohai Bay Basin"

Table 1

Nuclear magnetic resonance (NMR) experimental parameters of cores with different physical properties of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

岩心
编号		 水驱速度/
（mL·min-1）		 气驱速度/
（mL·min-1）		 储层类型 渗透率/
mD		 孔隙度/
%
LBJ1 0.1 0.1 中孔、特高渗 1 038.70 19.51
LBJ3 0.1 0.1 中孔、中渗 441.83 22.21
LBJ3 0.1 0.5 中孔、中渗 441.83 22.21
LBJ4 0.1 0.5 中孔、低渗 6.92 17.08

Fig. 2

Nuclear magnetic water-to-gas drive frequency curves of cores with different physical properties of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

Table 2

Relative contribution rate of oil displacement efficiency under different pore throat sizes in nuclear magnetic resonance experiment of Es32+3 reservoir in northern Liuzan area， Bohai Bay Basin"

岩心
编号		 水驱速度/
（mL·min-1）		 气驱速度/
（mL·min-1）		 水驱阶段中不同孔喉大小下驱油效率的
相对贡献率/%		 气驱阶段中不同孔喉大小下驱油效率的
相对贡献率/%
0.002~0.200 μm 0.200~20.000 μm 0.002~0.200 μm 0.200~20.000 μm
LBJ1 0.1 0.1 54.76 41.78 69.85 18.87
LBJ3 0.1 0.1 49.17 38.44 63.48 15.95
LBJ3 0.1 0.5 49.17 38.44 78.23 11.33
LBJ4 0.1 0.5 62.66 10.06 72.35 12.85

Fig. 3

Relationship between the cumulative pore distribution frequency of nuclear magnetic resonance and pore radius of cores with different physical properties of Es32+3 reservoir in northern Liuzan area， Bohai Bay Basin"

Fig. 4

Flowchart of long core displacement experiment of Es32+3 reservoir in northern Liuzan area， Bohai Bay Basin"

Table 3

Formation water ratio of long core displacement experiment of Es32+3 reservoir in northern Liuzan area, northern Bohai Bay Basin"

成分 MgCl2 CaCl2 NaCl Na2SO4 NaHCO3 Na2CO3
ρ（成分）/
（g·L-1）		 0.004 0.019 1.192 0.009 1.203 0.055

Table 4

Core basic parameters of long core displacement experiment of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

样品
编号		 长度/
cm		 直径/cm 渗透率/mD 储层类型 核磁
实验
1 5.552 2.472 415.785 中孔、中渗 否
2 7.030 2.442 143.411 中孔、中渗 否
3 6.322 2.474 170.890 低孔、中渗 否
4 6.238 2.472 173.073 中孔、中渗 否
5 6.048 2.478 16.304 中孔、低渗 否
6 5.424 2.504 14.655 中孔、低渗 否
7 4.246 2.472 39.009 中孔、低渗 否
8 5.816 2.482 289.171 低孔、中渗 否
9 4.724 2.492 441.832 中孔、中渗 是
10 4.432 2.452 473.096 中孔、中渗 否
11 5.334 2.452 501.114 中孔、高渗 否
12 5.916 2.414 502.717 中孔、高渗 否
13 6.142 2.458 550.401 中孔、高渗 否
14 3.178 2.472 572.580 中孔、高渗 否
15 6.718 2.438 673.276 中孔、高渗 否
16 6.168 2.452 311.137 中孔、中渗 否
17 6.570 2.464 3.219 低孔、特低渗 否
18 5.678 2.468 54.018 中孔、中渗 否
综合 101.536 2.464（平均值） 296.983（平均值） 中孔、中渗 —

Table 5

Long core displacement experiment results of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

长岩心驱替实验 储层
总驱替潜力值/mL		 注入量/PV 驱替效率（实验值）/% 驱替效率（理论值）/%
水驱
阶段		 水转气
驱阶段		 水驱驱
油效率		 水转气驱
驱油效率		 注气提高
驱油效率		 最大气驱驱液效率（以可动液体饱和度为基准） 最大气驱驱液效率（以总孔隙体积为基准）
①0倾角，含水率95% 64.249 1.192 2.112 52.52 72.89 20.37 82.26 72.98
②40°倾角，含水率95% 70.778 0.994 1.890 53.86 76.97 23.11 90.62 80.39
③40°倾角，含水率100% 67.338 1.375 2.387 55.07 78.49 23.42 86.22 76.49

Fig. 5

Results of long core displacement experiments at 0 dip angle and 40 ° dip angle of 95% water cut of Es32+3 reservoir in northern Liuzan area， Bohai Bay Basin"

Fig. 6

Results of long core displacement experiment under the condition of 0 dip angle and 95% water cut of Es32+3 reservoir in northern Liuzan area， Bohai Bay Basin"

Fig. 7

Results of long core displacement experiments under the condition of the same dip angle and different water cut of Es32+3 reservoir in northern Liuzan area， Bohai Bay Basin"

Fig. 8

Theoretical calculation results of the long core displacement experiment of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

Fig. 9

Permeability plane distribution of the numerical model of Es32+3 reservoir components in northern Liuzan area, Bohai Bay Basin"

Fig. 10

Relationship between gas drive recovery and gravity number of the long core displacement experiment of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

Fig. 11

Relationship between enhanced oil recovery by gas flooding and gravity number simulated by numerical model of Es32+3 reservoir in northern Liuzan area，Bohai Bay Basin"

Fig. 12

Stability discrimination under different gas injection rates based on the two-dimensional theoretical model of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

Fig. 13

Schematic diagram of the two-dimensional physical model of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

Fig. 14

Permeability distribution of the two-dimensional plate numerical simulation model of Es32+3 reservoir in northern Liuzan area， Bohai Bay Basin"

Table 6

Fluid composition of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

流体样品 x(组分)/%
N2 CH4 C2H6 C3H8 iC4/nC4 iC5/nC5 FC6 C7-11 C14-21
原油 0.000 70 0.181 30 0.010 00 0.010 30 0.038 10 0.045 10 0.054 10 0.442 02 0.218 38
干气 0.003 45 0.947 44 0.029 22 0.002 34 0.003 55 0.009 23 0.004 77 0 0

Table 7

Parameter conversion between target work area parameters and two-dimensional plate numerical simulation model parameters of Es32+3 reservoir in northern Liuzan area， Bohai Bay Basin"

参数名称 目标工区 二维模型
井距/m 200.00 0.17
储层厚度/m 30.00 0.03
油层温度/℃ 95.9 95.9
地层压力/MPa 30 30
孔隙度/% 19.5 19.5
渗透率/mD 265 265
生产时间/(a，min) 1 447
产液速度/（HCPV·a-1，
mL·min-1）		 0.060 0~0.080 0 0.003 7~0.004 0

Fig. 15

Evolution law of gas-liquid interface dip angle with injection-production ratio in the two-dimensional plate numerical simulation model of Es32+3 reservoir in northern Liuzan area， Bohai Bay Basin"

Fig. 16

Evolution law of pressure field with injection-production ratio of the two-dimensional plate numerical simulation model in Es32+3 reservoir of northern Liuzan area, Bohai Bay Basin"

Fig. 17

Curves of cumulative recovery with injection-production ratio in the two-dimensional plate numerical simulation model of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

Fig. 18

Variation of gravity number with injection-production ratio in the two-dimensional theoretical model of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

Fig. 19

Evolution law of gas-liquid interface morphology with injection-production ratio of the two-dimensional plate numerical simulation model of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

Table 8

Critical injection-production ratio obtained by the two-dimensional theoretical model and the numerical simulation model of Es32+3 reservoir in northern Liuzan area， Bohai Bay Basin"

注气速度/
（HCPV·a-1）		 不同模型模拟的临界注采比 临界
注采比		 实际地下
注采比
理论
模型		 界面
模型		 采收率
模型
0.006 — — 0.90 0.90 0.35
0.009 — — 0.80 0.80 0.31
0.012 — — 0.80 0.80 0.31
0.016 — — 0.60 0.60 0.23
0.020 ≥ 4.00 > 1.00 1.00 0.39
0.040 ≥ 4.00 ≥3.00 ≥ 3.00 3.00 1.17
0.060 ≥ 5.00 > 4.00 ≥ 4.00 4.00 1.56
0.080 ≥ 7.00 > 7.00 ≥ 6.00 6.00 2.35
0.100 ≥ 9.00 > 10.00 ≥ 9.00 9.00 3.52

Fig. 20

Discrimination of injection-production ratio of stable displacement under different gas injection rates in the gas injection gravity flooding production stage of Es32+3 reservoir in northern Liuzan area, Bohai Bay Basin"

Fig. 21

Schematic diagram of improved Dietz model integrating pressure funnel theory, geological engineering parameters and interface"

Fig. 22

Variation curves of cumulative injection-production ratio during gas injection gravity flooding stage of different well groups in Es32+3 reservoir， northern Liuzan area of Bohai Bay Basin"

Fig. 23

Stability discrimination of gas injection gravity flooding production stage of LB3 well group in Es32+3 reservoir in northern Liuzan area， Bohai Bay Basin"

Fig. 24

Production performance curve of gas injection gravity flooding production stage of LB3 well group in Es32+3 reservoir in northern Liuzan area， Bohai Bay Basin"

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