混积程度对储层孔喉的影响及其在（混积）砂岩储层分类中的应用——以伊拉克M油田中新统为例

兰浩翔; 范云杰; 伏美燕; 李可赛; 王龙; 周文

doi:10.19509/j.cnki.dzkq.tb20250402

混积程度对储层孔喉的影响及其在（混积）砂岩储层分类中的应用——以伊拉克M油田中新统为例

doi: 10.19509/j.cnki.dzkq.tb20250402

兰浩翔^1a,
范云杰^1a,
伏美燕^{1a, 1b,},
李可赛^{1a, 1b},
王龙²,
周文^{1a, 1b}

1a.
成都理工大学：能源学院
1b.
成都理工大学：油气藏地质及开发工程国家重点实验室，成都 610059
2.
中国海洋石油国际有限公司，北京 100028

详细信息

作者简介:
兰浩翔：XX

通讯作者:
xx

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- 文章访问数: 192
- PDF下载量: 11
- 被引次数: 0
出版历程
- 收稿日期: 2025-09-03
- 录用日期: 2026-12-30
- 修回日期: 2025-12-04
- 网络出版日期: 2025-12-30

Impact of mixing intensity on reservoir pore-throat structure and its application to (mixed) sandstone reservoir classification: A case study of Miocene of M Oilfield, Iraq

LAN Haoxiang^1a,
FAN Yunjie^1a,
FU Meiyan^{1a, 1b
,},
LI Kesai^{1a, 1b},
WANG Long²,
ZHOU Wen^{1a, 1b}

1a.
College of Energy
1b.
State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Chengdu University of Technology, Chengdu 610059, China
2.
CNOOC International Limited, Beijing 100028, China

More Information

Author Bio:
XX

Corresponding author: xx

摘要

摘要:
目的
混积砂岩储层受陆源碎屑与碳酸盐双重作用，储层非均质性极强，但目前混积程度对储层孔喉的定量控制机制尚不明确。本研究旨在明确混积度对储层孔喉结构的控制效应，并建立适用于混积砂岩的储层定量分类方案，为该类储层有利区预测提供支撑。
方法
以伊拉克 M 油田中新统 Asmari 组为研究实例，综合利用岩心观察、铸体薄片鉴定、实测孔渗、测井及地球化学测试资料，基于陆源碎屑−碳酸盐组分体积分数界定混积度，构建测井 S₁ 参数实现混积度定量识别；结合压汞、半渗透隔板、核磁共振开展多尺度孔喉表征，分析混积度与孔喉结构的耦合关系，并结合单井产能数据验证储层分类方案。
结果
研究表明：研究区发育含砂颗粒白云岩、白云质砂岩等多种混积岩，依据次要组分体积分数将混积划分为弱混积（10%～25%）与强混积（25%～50%）；混积度对砂岩储层孔喉改造作用显著，对碳酸盐岩储层孔隙度影响有限，但会明显破坏孔喉连通性；云质混积度低于 25% 时砂岩以原生粒间孔−缩颈型喉道组合为主，孔渗条件优越，高于 25% 后孔喉结构发生重构，晶间（溶）孔大量发育，孔渗性能显著衰减。厘定 H_jy 为 10%，25%，35% 3个关键阈值，以此将混积砂岩划分为 Ⅰ-Ⅳ 4类储层；基于比采油指数（SPI）产能统计证实四类储层产能逐级递减，分类方案与实际产能匹配良好。
结论
混积度是控制混积砂岩储层非均质性的核心地质因素，25% 是砂岩储层物性发生劣化的关键界限。融合混积度与孔喉结构的储层分类方案，可有效识别有利储层，为中东地区同类混积砂岩油气藏勘探开发提供地质参考依据。
- Asmari组 /
- 混合沉积 /
- 孔喉结构 /
- 混积储层 /
- 储层分类
Abstract:
Objective
Mixed siliciclastic–carbonate (mixed-sediment) reservoirs are widely developed in the Middle East, where complex interbedding and intermixing of terrigenous clastic and carbonate components lead to pronounced reservoir heterogeneity. At present, the quantitative control mechanism of mixing intensity over pore-throat structure remains poorly constrained, which restricts the prediction of high-quality reservoirs and efficient hydrocarbon development in these complex reservoirs. This study aims to clarify the controlling effect of mixing intensity on reservoir pore-throat structure and establish a quantitative reservoir classification scheme specifically for mixed sandstone reservoirs, thereby providing a geological basis for favorable reservoir evaluation of analogous mixed-sediment reservoirs.
Methods
Taking the Miocene Asmari Formation in M oilfield, Iraq, as the research object, multi-source datasets including core descriptions, thin-section observations, core-measured porosity and permeability, well-logging curves, and geochemical test data were comprehensively integrated. Based on the volume fractions of terrigenous clastic and carbonate components obtained from thin-section mineral quantification, mixing intensity was quantitatively defined, and a logging-derived S₁ parameter was constructed to realize continuous quantitative identification of mixing intensity in boreholes. Multi-scale pore-throat characterization techniques, including mercury-intrusion capillary pressure, semi-permeable diaphragm method, and nuclear magnetic resonance, were adopted to analyze the coupling relationship between mixing intensity and microscopic pore-throat structure. Single-well productivity data, characterized by the specific productivity index (SPI), were further applied to verify the rationality of the proposed reservoir classification scheme.
Results
The results showed that multiple types of mixed-sediment rocks, including sand-bearing granular dolostones and dolomitic sandstones, occurred in the study area. According to the volume fraction of minor components, mixed rocks were classified into weak-mixing (10%-25%) and strong-mixing (25%-50%) categories. Mixing intensity substantially modified pore-throat systems in sandstone reservoirs. In carbonate reservoirs, it had a limited effect on porosity but substantially impaired pore-throat connectivity. When the dolomitic mixing intensity H_jy was lower than 25%, sandstones were dominated by a combination of primary intergranular pores and necking throats, with favorable porosity and permeability. Once H_jy exceeded 25%, pore-throat structures were reconstructed, intercrystalline (dissolution) pores widely developed, and porosity and permeability degraded remarkably. Three critical threshold values of H_jy (10%, 25%, and 35%) were determined, based on which mixed sandstone reservoirs were classified into four types (Types Ⅰ–Ⅳ). Productivity statistics using SPI demonstrated a progressive decline in productivity from Type Ⅰ to Type Ⅳ, indicating good agreement between this classification scheme and actual production performance.
Conclusion
It is concluded that mixing intensity is the key geological factor controlling heterogeneity in mixed sandstone reservoirs, and 25% represents the critical threshold for the deterioration of sandstone reservoir properties. The proposed reservoir classification scheme integrating mixing intensity and pore-throat structure can effectively discriminate favorable reservoir intervals, and offers valuable geological references for hydrocarbon exploration and development of comparable mixed sandstone reservoirs across the Middle East.
- Asmari Formation /
- mixed sedimentation /
- pore-throat structure /
- mixed reservoir /
- reservoir classification

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图 1 M油田构造位置图

Figure 1. Tectonic location map of M oilfield

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图 2 M油田综合柱状图

GR为自然伽马；SP为自然电位；CAL为井径；AC为声波时差；DEN为密度；CNL为补偿中子；LLD为深侧向电阻率；LLS为浅侧向电阻率；下同

Figure 2. Comprehensive stratigraphic column of M oilfield

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图 3 Asmari组混积岩岩石分类图

Figure 3. Classification of mixed-sediment rocks of Asmari Formation

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图 4 混积岩类型薄片照片

a. M33井，3013.8 m，含砂颗粒白云岩；b. M33井，3036 m，含砂颗粒云灰岩；c. M26井，3217 m，砂质颗粒白云岩；d. 26井，3170.5m，含白云石膏质砂岩；e. 26井，3135.7 m，含砂灰岩；f. 26井，3151 m，砂质灰岩；g. 26井，3154.95 m，白云质砂岩；h. 61井，3080 m，含灰砂质白云岩

Figure 4. Thin-section microphotographs of mixed-sediment rocks

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图 5 智能识别模型混淆矩阵图

Figure 5. Confusion matrix of intelligent identification model

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图 6 卷积神经网络（CNN）模型损失函数 (a) 与准确率 (b) 随训练轮次变化

Figure 6. Variation of loss function (a) and accuracy (b) of convolutional neural network (CNN) model with training epochs

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图 7 M41井的混积度识别结果

Figure 7. Identification results of mixing intensity in Well M41

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图 8 研究区储集空间薄片照片

a. 33井，3025.4 m，粒间孔；b. 26井，3174.8 m，晶间溶孔+晶间隙；c. 26井，3053.4 m，铸模孔；d. 33井，3045.1 m，生物体腔孔；e. 26井，3074.1 m，粒内溶孔；f. 26井，3071.6 m，粒间溶孔；g. 33井，3006.2 m，粒缘缝；h. 26井，3151 m，溶缝

Figure 8. Thin-section microphotographs of reservoir pore space in study area

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图 9 砂岩类储层孔、渗频率分布图（N为样品书；因四舍五入，各子图频率之和可能不严格等于100%；下同）

Figure 9. Frequency distribution of porosity and permeability in sandstone reservoirs

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图 10 碳酸盐岩类储层孔、渗频率分布图

Figure 10. Frequency distribution of porosity and permeability in carbonate reservoirs

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图 11 孔隙度、渗透率与混积度交会图（H_jy为砂岩储层的云质混积度；H_js为碳酸盐岩（云岩）储层的砂质混积度；R²为决定系数；下同）

Figure 11. Crossplots of porosity and permeability versus mixing intensity

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图 12 混积度对砂岩与碳酸盐岩储层孔喉结构的差异化影响示意图

Φ，K为对应样品实测值

Figure 12. Schematic diagram of differential effects of mixing intensity on pore-throat structure of sandstone and carbonate reservoirs

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图 13 研究区砂岩储层渗透率与R₃₅、可流动孔喉体积百分数及孔隙度的交会关系图版

Figure 13. Crossplots of permeability versus R₃₅, volume fraction of flowable pore throats, and porosity in sandstone reservoirs in study area

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图 14 M油田砂岩伪毛管力曲线分布图

R₃₅为进汞35%饱和度对应的孔喉半径；r为相关系数

Figure 14. Distribution of pseudo-capillary pressure curves for sandstones in M oilfield

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图 15 研究区开发井初产统计

Figure 15. Initial-production statistics of development wells in study area

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表 1 强混积和弱混积的定量识别标志

Table 1. Quantitative discrimination criteria for strong and weak mixing intensity

按混积度分类	组分特征/%	S₁/%
强混积	φ（次要组分）[25, 50]	[0.25, 0.75]
弱混积	φ（次要组分）[10, 25)	[10, 25)，(75, 90]
注：S₁为测井识别用的混积度参数，为砂岩组分占砂岩、灰质、白云质三组分总量的体积分数，下同

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