CO2非混相驱前缘运移及气窜规律室内实验研究

doi:10.13809/j.cnki.cn32-1825/te.2022.05.008

Abstract

Abstract:

Currently, there are few works on the laws of front migration and gas channeling with laboratory experiments from the aspect of CO₂ sweep efficiency. Therefore, a visual physical simulation device is used to carry out the physical simulation experiment of CO₂ immiscible flooding of slab core. The influences of factors such as crude oil viscosity, reservoir permeability, reservoir heterogeneity and injection rate on the migration of CO₂ immiscible flooding front and gas channeling laws are analyzed. The study found that under the conditions of constant flow injection in injection wells and constant pressure production in production wells, the viscosity of crude oil decreases, the permeability decreases, the reservoir is homogeneous, and the injection speed increases, which will lead to an increase in the recovery degree of CO₂ immiscible flooding. Meanwhile, the decrease in the viscosity of crude oil, the lower the permeability, and the increase in the injection rate, also lead to the enhancement of the ability of the oil well to continue to expand sweep factor after gas breakthrough, that is, it can alleviate gas channeling. It is concluded that under the condition of constant flow injection in injection wells and constant pressure production in production wells, high injection rate development can alleviate gas channeling and obtain better development results. When the injection rate increased from 0.1 mL/min to 2 mL/min, the recovery increased from 15.4 % to 35.3 %, and the sweep factor difference increased from 8.3 % to 26.2 %. This research is of great significance for CO₂ immiscible flooding gas channeling suppression and enhanced oil recovery.

Key words: CO₂ immiscible flooding, front migration, gas channeling, sweep characteristics, laboratory experiment

CLC Number:

TE348

Weijun KONG,Chuanzhi CUI,Zhongwei WU, et al. Laboratory experiment of front migration and gas channeling of CO₂ immiscible flooding[J]. Petroleum Reservoir Evaluation and Development, 2022, 12(5): 764-776.

Figures/Tables 19

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组次	影响因素	参数设计	常规参数	注采井网
1	原油黏度	2 mPa·s	驱替速度0.5 mL/min	一注一采
2		10 mPa·s
3		15 mPa·s
4		20 mPa·s
5	储层渗透率	低渗透率（200×10^-3μm²）	原油黏度10 mPa·s; 驱替速度0.5 mL/min	一注一采
6		中低渗透率（500×10^-3μm²）
7		中高渗透率（750×10^-3μm²）
8		高渗透率（1 000×10^-3μm²）
9	非均质性	均质（级差为1）	原油黏度10 mPa·s; 驱替速度0.5 mL/min	一注两采
10		低级差（级差为1.25）
11		中级差（级差为1.7）
12		高级差（级差为2.5）
13	注入速度	0.1 mL/min	原油黏度10 mPa·s	一注一采
14		0.5 mL/min
15		1.0 mL/min
16		2.0 mL/min

原油黏度（mPa·s）	0.25L	0.5L	0.75L	1L（见气时）
2
10
15
20

原油黏度（mPa·s）	共驱替20 min （0.28 PV）	共驱替30 min （0.42 PV）		原油黏度（mPa·s）	共驱替20 min （0.28 PV）	共驱替30 min （0.42 PV）
2					15
10					20

储层渗透率	0.25L	0.5L	0.75L	1L（见气时）
低渗透率（200×10^-3μm²）
中低渗透率（500×10^-3μm²）
中高渗透率（750×10^-3μm²）
高渗透率（1 000×10^-3μm²）

储层渗透率	共驱替20 min （0.28 PV）	共驱替30 min （0.42 PV）		储层渗透率	共驱替20 min （0.28 PV）	共驱替30 min （0.42 PV）
低渗透率					中高渗透率
中低渗透率					高渗透率

Laboratory experiment of front migration and gas channeling of CO₂ immiscible flooding

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储层渗透率级差	0.25L	0.5L	0.75L	1L（见气时）
均质
低级差
中级差
高级差

Laboratory experiment of front migration and gas channeling of CO2 immiscible flooding

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Laboratory experiment of front migration and gas channeling of CO₂ immiscible flooding