本期精选发表于《油气地质与采收率》的5篇双语文章，从微观驱替机理、多相驱替实验、现场注采参数优化、CO2前置压裂增产、开发效益评估等多个维度，系统拆解CCUS-EOR技术体系，以期为油气田绿色开发、老油田增效改造提供前沿理论与技术参考。
“双碳”背景下非常规油气藏CO2提高采收率技术研究现状及展望
Current status and future prospects of CO2-enhanced recovery technologies for unconventional oil and gas reservoirs based on carbon peaking and carbon neutrality goals
【摘要】在全球碳中和战略驱动下，非常规油气藏开发与碳捕集、利用与封存(CCUS)技术的耦合创新已成为破解能源-环境双重约束的核心路径。系统梳理与评述CO2提高采收率技术在非常规油气藏开发中的机理、应用现状及技术瓶颈，并基于CCUS全产业链视角提出未来技术融合规模化发展的突破方向，进而探讨其在提高油气采收率与实现碳中和目标中的双重价值。非常规油气藏因其低渗透率、复杂孔隙结构及非连续成藏特征，传统开采技术难以实现经济高效开发。研究表明，CO2凭借其独特的超临界物理化学性质，通过周期性吞吐、驱替、压裂、热交换及CO2辅助渗吸等多种提高采收率技术显著改善开发效果，其与原油、地层水及岩石的界面相互作用是影响驱替效果的核心控制因素，需结合油藏非均质性与温度、压力条件进行精准调控。当前CO2提高采收率技术仍面临气源分布不均、运输成本高、储层非均质性强和CCUS产业化不足等挑战。基于全产业链规模化视角展望未来，亟需通过高效低能耗捕集技术突破、CO2驱油参数优化和封存等技术创新，配合碳市场交易机制和政策支持，构建“捕集-驱油-封存”全产业链价值闭环。CO2提高采收率技术兼顾非常规油气高效开发与碳减排需求，为能源转型提供双重价值，将会助力全球碳中和目标实现。
【Abstract】Under the global carbon neutrality mandate, the integrated innovation of unconventional oil and gas reservoir development with carbon capture, utilization, and storage (CCUS) technology has emerged as a critical pathway to address the dual challenges of energy security and environmental sustainability. This paper aims to systematically review and evaluate the mechanisms, current applications, and technical bottlenecks of CO2-enhanced oil recovery (CO2-EOR) technologies in the development of unconventional oil and gas reservoirs. From the perspective of the full CCUS industrial chain, it proposed breakthrough directions for the future large-scale integration of these technologies and further explored their dual value in enhancing oil and gas recovery and achieving carbon neutrality goals. Unconventional oil and gas reservoirs, characterized by low permeability, complex pore structures, and discontinuous accumulation, present significant economic and technical challenges for conventional extraction methods. Research indicates that, by virtue of its unique supercritical physicochemical properties, CO2 can significantly improve reservoir development performance through a variety of EOR technologies, such as cyclic huff-and-puff, displacement, fracturing, heat exchange, and CO2-assisted imbibition. The interfacial interactions among CO2, crude oil, formation water, and reservoir rocks are the core controlling factors affecting displacement efficiency, which therefore necessitate precise regulation in conjunction with reservoir heterogeneity as well as temperature and pressure conditions. Current implementation of CO2-EOR remains constrained by several factors, including uneven distribution of CO2 sources, high transportation costs, strong reservoir heterogeneity, and underdeveloped CCUS industrial infrastructure. Looking forward from a full industrial chain perspective, advancements are urgently needed in high-efficiency and low-energy CO2 capture technologies, optimization of flooding and storage parameters, and the establishment of carbon market mechanisms complemented by supportive policy frameworks. These steps are essential to realize a closed-loop “capture, flooding, and storage” industrial chain. CO2-EOR technology offers a dual advantage by enabling the efficient development of unconventional oil and gas resources while simultaneously reducing carbon emissions. This integrated approach provides substantial value for the ongoing energy transition and supports the global commitment to achieving carbon neutrality.
DOI: 10.13673/j.pgre.202505029
基于前缘均衡调控的低渗透油藏CO2驱注采参数优化——以胜利油田F142井组为例
Optimization study on injection-production parameters of CO2 flooding in low-permeability reservoirs based on front uniformity regulation: A case study of F142 well group in Shengli Oilfield
【摘要】在CO2驱油封存过程中，前缘均衡程度优化对于改善驱油封存效果至关重要。为解决由储层平面非均质性与注采井网影响导致的低渗透油藏CO2驱前缘不均衡的问题，建立井组机理模型，用以模拟注采过程中的非均衡前缘，通过自动优化算法，建立CO2驱注采参数优化方法以实现对前缘的调控。通过油藏工程方法界定了优化过程中的合理注采参数，并分别对胜利油田F142井组的连续注气、注采耦合以及水气交替3种注采方案进行参数优化应用研究，通过封存率、生产气油比以及换油率等指标评估了前缘优化效果。结果表明：在CO2驱注采参数优化中，优化前缘均衡程度的同时会增加封存率，降低整体生产气油比并提高换油率；对于F142井组，生产井同时见气时间早更有利于驱油，而见气时间晚更有利于封存。
【Abstract】In the CO2 flooding process, the optimization of the uniformity degree of the front is crucial for improving the effectiveness of CO2 flooding. To address the issue of uneven CO2 flooding front in the reservoirs caused by planar heterogeneity of the reservoir and the influence of injection-production well patterns, a well group model was established to simulate the non-uniform front during the injection-production process. Through an automatic optimization algorithm, a CO2 flooding injection-production parameter optimization method was developed to achieve control over front uniformity. Using reservoir engineering methods, the reasonable range of injection-production parameters during the optimization process was defined. Parameter optimization applications were studied for three injection schemes in the F142 well group in Shengli Oilfield: continuous gas injection, injection-production coupling, and water-alternating-gas (WAG) injection. The effects of front optimization were evaluated using metrics such as the storage ratio, produced gas-oil ratio (GOR), and oil exchange ratio. The results show that optimizing the uniformity degree of the CO2 front simultaneously increases the CO2 storage ratio, reduces the overall produced GOR, and enhances the oil exchange ratio in CO2 flooding injection-production parameter optimization. For the F142 well group, earlier simultaneous gas breakthrough in production wells is more favorable for oil displacement, while later gas breakthrough is more favorable for CO2 storage.
DOI: 10.13673/j.pgre.202504054
致密砂砾岩CO2前置压裂增产机理与模型应用
Stimulation mechanism and model application of CO2 pre-pad fracturing for production enhancement in tight glutenite reservoirs
【摘要】致密砂砾岩储层普遍具有低孔低渗透、流动阻力大和自然产能低等特征，亟需通过有效的改造方式提高采收率。CO2前置压裂作为一种兼具增产与储气作用的高效改造方法，近年来受到广泛关注，但目前仍缺乏标准化模型与系统优化参数的研究。针对该问题，基于致密砂砾岩油藏特性，构建了CO2前置压裂渗流与压裂模型，并通过理论分析与数值模拟相结合的方法，对不同注入条件下的裂缝扩展规律、油气驱替特征及增产效果进行了系统研究。研究采用扩展双重介质离散裂缝模型(EDFM)和CO2驱动油气实验，分析了注入量、注入排量、焖井时间等关键参数对改造效果的影响。结果表明，该方法在单因素与多因素条件下均表现出良好的稳产与增产效果，CO2前置压裂能显著改善储层渗透性与压裂液返排效率，提升油气驱替能力，推荐CO2注入量为200～300 m3/段，注入排量约为8 m3/min，簇间距为15～20 m，焖井时间不宜超过40 d。
【Abstract】Tight glutenite reservoirs are generally characterized by low porosity, low permeability, high flow resistance, and poor natural productivity, making effective stimulation methods essential to enhance oil recovery. CO2 pre-pad fracturing, as an effective stimulation method for enhanced production and gas storage, has attracted increasing attention in recent years, yet standardized modeling and system parameter optimization remain insufficient. To address this issue, based on the characteristics of tight glutenite reservoirs, a flow and fracturing model for CO2 pre-pad fracturing was developed. By using a combined approach of theoretical analysis and numerical simulation, a systematic study was conducted on fracture propagation patterns, hydrocarbon displacement characteristics, and stimulation performance under different injection conditions. This study employed the embedded discrete fracture model (EDFM) and CO2-driven hydrocarbon experiments to analyze the influence of key parameters on stimulation performance, such as injection volume, rate, and shut-in time. The results indicate that CO2 pre-pad fracturing significantly improves reservoir permeability and fracturing fluid recovery, thereby enhancing oil and gas displacement efficiency. The recommended parameters are an injection volume of 200–300 m3 per stage, an injection rate of approximately 8 m3/min, a cluster spacing of 15–20 m, and a shut-in time not exceeding 40 days.
DOI: 10.13673/j.pgre.202507017
CO2-油、水-油两相及CO2-水-油三相驱替实验对比研究
Comparative study on CO2-oil, water-oil two-phase and CO2-water-oil three-phase displacement experiments
【摘要】针对高含水期油藏剩余油难以动用及CO2封存稳定性不足的问题，基于真实砂岩CT扫描构建刻蚀图案，加工获得玻璃刻蚀微模型，并搭建高温高压(50℃、6.0 MPa)可视化微流控实验体系，依次开展CO2-油、水-油两相及CO2-水-油三相驱替实验，实现多相流动过程的实时可视化与饱和度定量计算。结果表明：相同驱替速率下，CO2-油两相驱替受毛细管力控制显著，前缘在毛细管力阈值差与黏度比不利作用下呈不稳定推进，易发生气窜，残余油饱和度为0.70，CO2封存饱和度为0.30；水-油两相呈活塞式推进，水锁效应与毛细管力共同形成以“H”型柱状段塞为主的残余油分布，残余油饱和度降至0.21；水驱后再注CO2时，形成“气驱水、水再驱油”的双重驱替机理，水膜的润湿阻隔与油膜沿界面的铺展协同作用有效抑制前缘失稳并增强残余油动用，残余油饱和度进一步降至0.15，CO2封存饱和度升至0.45。研究表明，“先水驱-后注CO2”的策略可兼顾提高采收率与增强CO2滞留，有助于高含水期油藏CO2注入工艺的优化设计与封存安全性提升。
【Abstract】To address the challenges of mobilizing residual oil and ensuring the stability of CO2 sequestration in high-water-cut reservoirs, based on CT scans of real sandstone, etching patterns were constructed and used to fabricate glass-etched micromodels. A high-temperature and high-pressure (50 °C, 6.0 MPa) visual microfluidic experimental system was then set up. Displacement experiments were conducted sequentially for CO2-oil and water-oil two-phase systems, as well as for CO2-water-oil three-phase systems, enabling real-time visualization of multiphase flow processes and quantitative calculation of saturation. The results show that the CO2-oil two-phase displacement is strongly governed by capillary forces under the same injection rate. Due to the adverse effects of the capillary force threshold difference and viscosity ratio, the displacement front advances in an unstable manner, making it prone to gas channeling. The residual oil saturation is 0.70, and the CO2 sequestration saturation is 0.30. The water-oil two-phase displacement advances in a piston-like manner. Under the combined effects of water blockage and capillary forces, the residual oil primarily distributes as “H”-shaped columnar slugs, with the saturation decreasing to 0.21. When CO2 is injected after water flooding, a dual-displacement mechanism of “CO2 displacing water and water re-displacing oil” is formed. The synergistic action of the wetting barrier from the water film and the spreading of the oil film along the interface effectively suppresses front instability and enhances the mobilization of residual oil, further reducing the residual oil saturation to 0.15 and increasing the CO2 sequestration saturation to 0.45. The study indicates that the strategy of “water flooding followed by CO2 injection” simultaneously achieves enhanced oil recovery and increased CO2 retention, providing valuable insights for optimizing CO2 injection strategies and improving sequestration safety in high-water-cut reservoirs.
DOI: 10.13673/j.pgre.202509033
基于CO2驱替前缘扩展的低渗透油藏混相带时空演化机理
Spatiotemporal evolution mechanism of miscible zone in low-permeability reservoirs based on CO2 flooding front propagation
【摘要】在“双碳”战略背景下，CO2驱替被认为是低渗透油藏提高采收率与地质封存兼顾的优选方案，但其现场效果与预期存在偏差。为明确CO2驱替过程中油气混相带的时空演化机理，开展了长岩心CO2驱替物理模拟实验并辅以跨尺度数值模拟，系统刻画了CO2驱替过程中混相压力前缘、相前缘和组分前缘的差异拓展规律以及混相带动态演化行为。结果表明，受油气组分运移特征和多次接触作用影响，混相压力前缘推进速度最快，相前缘推进速度慢于组分前缘，造成了混相带分布呈现典型的时变性与空变性。提升油气混相程度有利于抑制CO2组分前缘运移，延缓CO2逃逸通道的扩展。此外，注气速度和注气量对前缘运移规律具有显著调控作用，当CO2注入量从0.2 PV提升至0.6 PV时，相前缘增幅达68%，扩大了油气作用带宽度。过快注气速度容易引发组分前缘快速运移，加剧气窜风险。油藏的非均质性导致混相带分布范围更加复杂，当基质渗透率由1.0×10-3μm2增至15.0×10-3μm2时，CO2相波及系数增幅达57.9%。裂缝渗透率增大导致组分前缘沿高渗透通道运移，造成混相带分布不均匀。
【Abstract】Under the “carbon peaking and carbon neutrality” strategy, CO2 flooding is regarded as a preferred approach to simultaneously enhance oil recovery and achieve geological storage in low-permeability reservoirs, yet its field performance often falls short of expectations. To clarify the spatiotemporal evolution mechanism of the oil-gas miscible zone during CO2 flooding, physical simulation experiments of long-core CO2 flooding were conducted and complemented with multi-scale numerical simulations. The study systematically characterized the differential propagation of miscible pressure fronts, phase fronts, and compositional fronts, as well as the dynamic evolution of the miscible zone during CO2 flooding. Results show that, influenced by hydrocarbon component migration characteristics and multi-contact interactions, the miscible pressure front advances fastest, while the phase front lags behind the compositional front, leading to pronounced temporal and spatial variability in miscible zone distribution. Enhancing miscibility helps suppress the advance of the compositional front and delays the development of CO2 breakthrough channels. Moreover, injection rate and volume exert significant regulatory effects on front propagation: when the injected CO2 volume increases from 0.2 PV to 0.6 PV, the phase front extension reaches 68%, effectively broadening the miscible zone. However, excessive injection rates accelerate compositional front migration and aggravate gas channeling risks. Reservoir heterogeneity further complicates miscible zone distribution; when matrix permeability rises from 1.0 × 10−3 μm2 to 15.0 × 10−3 μm2, the CO2 phase sweep efficiency increases by 57.9%, whereas higher fracture permeability facilitates preferential compositional front migration through high-permeability pathways, resulting in uneven miscible zone distribution.
DOI: 10.13673/j.pgre.202509039
期刊推荐
主管单位：中国石油化工集团有限公司
主办单位：中国石化胜利油田分公司
刊号：ISSN 1009-9603，CN 37-1359/TE
创刊时间：1994年
期刊宗旨及涵盖范围：
《油气地质与采收率》是一本报道国内外油气普查、勘探与开发成果，反映石油地质与工程领域研究水平的科技期刊。刊物以探讨“油气勘探开发新理论、新方法”和“提高油气采收率技术”为主题，内容涵盖油气勘探开发主业的各个专业方向。读者对象主要涵盖国内外从事石油天然气勘探与开发相关专业的科研院校的专家学者群体。
主要栏目：油气地质、油气采收率、专家论坛、学术争鸣、青年学者专栏、新能源与碳中和等。
中国知网“中文精品学术期刊外文版数字出版工程”（简称JTP）自2015年启动，已与400余种学术期刊合作出版了7万余篇双语对照论文，积累了丰富的学术翻译/英语加工/学术推广经验。形成了集双语出版、主题电子书出版、双语讲座视频制作、期刊英文内容编校加工、资讯编译、海外推广为一体的全方位服务体系，全面助力期刊提升国际影响力。感兴趣的朋友请联系
热门跟贴