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Research on integrated CO2 huff and puff and displacement for enhanced shale oil recovery in Subei Basin
- Petroleum Reservoir Evaluation and Development Vol. 16, Issue 2, Pages: 225-237(2026)
- 作者机构：
1.中国石化华东油气分公司，江苏 南京 210019
2.页岩油气富集机理与高效开发全国重点实验室，北京 102206
3.中国石化页岩油气勘探开发重点实验室，北京 102206
4.中国石化石油勘探开发研究院，北京 102206
- 作者简介：
- 基金信息：
DOI：10.13809/j.cnki.cn32-1825/te.2025340
CLC： TE122.3Received：17 October 2025，
Published：26 March 2026
- 稿件说明：
移动端阅览
姚红生, 梅俊伟, 唐建信, 等. 苏北盆地页岩油注CO2吞驱一体提高采收率研究[J]. 油气藏评价与开发, 2026, 16(2): 225-237.
YAO Hongsheng, MEI Junwei, TANG Jianxin, et al. Research on integrated CO2 huff and puff and displacement for enhanced shale oil recovery in Subei Basin[J]. Petroleum Reservoir Evaluation and Development, 2026, 16(2): 225-237.
姚红生, 梅俊伟, 唐建信, 等. 苏北盆地页岩油注CO2吞驱一体提高采收率研究[J]. 油气藏评价与开发, 2026, 16(2): 225-237. DOI： 10.13809/j.cnki.cn32-1825/te.2025340.
YAO Hongsheng, MEI Junwei, TANG Jianxin, et al. Research on integrated CO2 huff and puff and displacement for enhanced shale oil recovery in Subei Basin[J]. Petroleum Reservoir Evaluation and Development, 2026, 16(2): 225-237. DOI： 10.13809/j.cnki.cn32-1825/te.2025340.
摘要
针对页岩油体积压裂后衰竭开发递减快和采收率低等核心难题，通过机理实验-模型构建-矿场验证的研究思路，探究了苏北盆地页岩油注CO₂吞驱一体提高采收率的可行性及优化策略。首先开展页岩岩心渗吸、溶蚀、注CO
2
吞吐与驱替等多机制渗流实验，揭示不同流体作用下孔隙结构演变及渗吸置换效率差异，定量表征CO
2
吞驱联作模式下烃类动用特征、压力传播、波及效率；最终结合实验机理与数值模拟，优化注CO₂开发关键技术政策（如吞吐轮次、气水交替时机等）。实验研究表明：①碳酸水条件下可显著改善页岩孔隙结构，渗吸置换平衡时间缩短为地层水的15%；②CO₂吞吐优先动用轻烃组分，增油量随吞吐轮次增加呈先快后缓趋势，前3个轮次增油效果较好，增油量占比90%以上；③吞吐后岩心经渗吸预处理，注CO₂驱替压力梯度更高，促使CO
2
能进入更小孔隙，且抑气窜能力增强、波及范围更大，驱替效率提升4.24%。据此，结合组分数值模型优化提出页岩油“3个轮次吞吐+气水交替驱”开发模式，优选自喷生产结束为吞吐、驱替注气时机，充分发挥混相、气水交替扩波、抑气窜等作用，进一步扩大CO₂动用范围和程度，比衰竭开发提高采收率12.1%。通过矿场2口井试注，证明了苏北页岩油具备良好的注气能力，其中LY1-1井首轮吞吐峰值日产油量达27.9 t，预计累计增油量为2 500 t，换油率为0.25 t/t（每注入1 t CO
2
获得的产油量），达到阶段预期目标，证实苏北页岩油具备良好的注CO₂开发前景。
Abstract
To address the core challenges such as rapid decline and low recovery factor during depletion development after volume fracturing
this study investigated the feasibility and optimization strategies of integrated CO
2
huff and puff and displacement for enhancing shale oil recovery in the Subei Basin
following a research approach of mechanism experiments-model construction-field verification. First
multi-mechanism seepage experiments
including shale core imbibition
dissolution
and CO
2
huff and puff and displacement
were conducted to reveal pore structure evolution
and differences in imbibition and displacement efficiency under the influence of different fluids. The characteristics of hydrocarbon mobilization
pressure propagation
and sweep efficiency in the integrated CO
2
huff and puff and displacement mode were quantitatively characterized. Finally
based on the experimental mechanisms and numerical simulation
key technical policies for CO
2
injection development (e.g.
huff and puff cycles and water-alternating-gas (WAG) timing) were optimized. The experimental results showed that: (1) Under carbonated water conditions
shale pore structures were significantly improved
and the imbibition-displacement equilibrium time was shortened to 15% of that under formation water. (2) CO
2
huff and puff preferentially mobilized light hydrocarbon components
and the oil increment increased rapidly at first and then slowed as the huff and puff cycles increased
with the first three cycles accounting for over 90% of the total oil increment. (3) After huff and puff
imbibition pretreatment of the shale cores resulted in a higher CO
2
displacement pressure gradient
enabling CO
2
to enter smaller pore spaces
strengthening gas channeling suppression and expanding the sweep range
and increasing displacement efficiency by 4.24%. Based on these results
a shale oil development mode of “three-cycle huff and puff + WAG drive” was proposed and optimized using a compositional numerical model
and the end of natural-flow production was selected as the timing for huff and puff and displacement gas injection. This mode fully leveraged miscibility
WAG-driven sweep expansion
and gas channeling suppression
thereby further expanding the extent and degree of CO
2
mobilization and increasing recovery by 12.1% compared with depletion development. Pilot injection tests in two wells confirmed that Subei shale oil had favorable gas injection capability. For well LY1-1
the peak daily oil production in the first huff and puff cycle reached 27
.9 t
the cumulative oil increment was estimated to be 2 500 t
and the oil exchange ratio was 0.25 t/t (oil produced per 1 t of CO₂ injected)
meeting the phased expected targets and confirming the promising development prospects of CO
2
injection in Subei shale oil.
关键词
Keywords
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