深层低渗凝析气藏气驱适应性研究

doi:10.13809/j.cnki.cn32-1825/te.2024.03.002

摘要/Abstract

摘要：

针对深层低渗凝析气藏由衰竭开采转变为气驱开发过程中适应性不明确的问题，综合采用PVT（地层流体高压物性）分析仪、长岩心驱替物理模拟技术和数值模拟计算方法，开展了一系列评价研究。通过对比分析注CO₂、天然气（伴生气、CH₄）、N₂对凝析气体系高压物性影响与提高凝析油采出程度情况，明确了深层低渗凝析气藏气驱的适应性。实验结果表明：CO₂在凝析油中的溶解度和溶解气油比最大，具有较强降低凝析气藏饱和压力和露点压力的特点，提高凝析油采出程度的效果最佳。同时，采用长岩心物理模拟技术针对CO₂驱进行了注入时机、注入方式、注气速度优化研究，明确了在露点压力以上脉冲式注气效果更好，为注气开发技术政策及现场方案的实施提供数据支撑。

关键词: 凝析气藏, 深层低渗, 注气介质, 气驱适应性, 参数优化

Abstract:

The transition from depletion mining to gas flooding in deep low permeability condensate gas reservoirs poses significant adaptability challenges. To address these, a series of evaluation studies were conducted using the Pressure-Volume-Temperature（PVT）analyzer, long core displacement physical simulation technology, and numerical simulation calculations. This research specifically examines the impacts of CO₂ injection, natural gas（associated gas or pure CH₄）, and nitrogen（N₂）on the high-pressure physical properties of condensate gas systems and their potential to improve condensate oil recovery. Comparative analyses reveal that CO₂, due to its high solubility and favorable gas-oil dissolution ratio in condensate oil, significantly reduces the saturation pressure and dew-point pressure of condensate gas reservoirs, thereby offering the most substantial improvement in oil recovery rates. Further optimization studies using long core physical simulation technology focused on injection timing, modes, and rates for CO₂ flooding. It was determined that pulsed gas injection strategies are particularly effective when implemented above the dew-point pressure. These findings provide essential data to support the formulation of technical policies and field plans for gas injection development in such challenging reservoir conditions.

Key words: condensate gas reservoir, deep low permeability, gas injection medium, gas flooding adaptability, parameter optimization

中图分类号:

TE357

李中超,齐桂雪,罗波波等. 深层低渗凝析气藏气驱适应性研究[J]. 油气藏评价与开发, 2024, 14(3): 324-332.

Zhongchao LI,Guixue QI,Bobo LUO, et al. Gas flooding adaptability of deep low permeability condensate gas reservoir[J]. Petroleum Reservoir Evaluation and Development, 2024, 14(3): 324-332.

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凝析气藏名称	埋深/m	平均孔隙度/%	渗透率/（10^-3μm²）	凝析油含量/（mg/L）
雅克拉气藏	4 370~4 450	上气层12.40	上气层62.27	251
雅克拉气藏	4 370~4 450	下气层12.90	下气层120.08	251
大涝坝气藏	4 950~5 170	上气层15.68	上气层59.74	653~875
		中气层71.36	中气层49.70
		下气层15.28	下气层203.08
大张坨气藏	2 560~2 675	23.50	113.00~459.80	630
柯克亚气藏	2 960~4 000	17.46	62.30	500
目标气藏	2 576~4 200	12.10	≤5	53~388

注入气体		注入量摩尔比	凝析油体系饱和压力/MPa
无注气		0	19.541
CO₂		0.05	21.112
		0.10	21.204
		0.20	23.305
		0.30	26.345
天然气（伴生气）		0.05	20.901
		0.10	22.292
		0.20	25.331
天然气（CH₄）		0.05	21.130
		0.10	22.654
		0.20	26.852
N₂		0.05	22.292
N₂		0.10	26.603
不同CO₂体积分数的伴生气	90%	0.10	21.568
	80%		21.602
	60%		21.762
	40%		21.996
	20%		22.275
	10%		22.290

类别	注入气量/ 摩尔比	溶解气油比/ （m³/m³）	凝析油体系黏度变化值/（mPa·s）	液相体积增量/%	产出气凝析油量/%
凝析油	0	122	0	0	0
CO₂	0.2	156	0.098	4.5	0.25
	0.4	183	0.082	8.2	0.42
	0.6	222	0.076	10.5	0.78
	0.8	236	0.069	12.6	1.32
	1.0	251	0.073	11.1	2.02
天然气（CH₄）	0.2	121	0.118	-0.5	0.18
	0.4	120	0.119	-1.8	0.35
	0.6	121	0.120	-3.8	0.47
	0.8	122	0.122	-5.0	0.50
	1.0	122	0.124	-6.1	0.61
N₂	0.2	100	0.125	-0.5	0.12
	0.4	90	0.130	-2.5	0.19
	0.6	75	0.135	-3.9	0.25
	0.8	70	0.141	-5.2	0.30
	1.0	68	0.146	-8.9	0.34