高石梯区块震旦系灯四段台缘与台内综合对比及开发对策建议

胡浩; 汪敏; 隆辉; 江林; 沈秋媛; 吴东; 田兴旺

doi:10.11932/karst20250217

高石梯区块震旦系灯四段台缘与台内综合对比及开发对策建议

doi: 10.11932/karst20250217

胡浩^1,,
汪敏¹,
隆辉¹,
江林¹,
沈秋媛¹,
吴东¹,
田兴旺²

1.
中国石油西南油气田分公司蜀南气矿, 四川泸州 646200
2.
中国石油西南油气田分公司勘探开发研究院, 四川泸州 646200

基金项目: 国家科技重大专项专题“四川盆地震旦系—古生界深层勘探目标评价”（2017ZX05008-005-003）；中国石油西南油气田分公司科技处项目（20210301-02）

详细信息

作者简介:
胡浩（1987－），男，工程师，研究生，主要研究方向开发地质学。E-mail：676569615@qq.com

中图分类号: P618.13
计量
- 文章访问数: 6
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- 被引次数: 0
出版历程
- 收稿日期: 2023-12-16
- 录用日期: 2024-06-19
- 修回日期: 2024-05-17
- 刊出日期: 2025-04-20

Comprehensive comparison and development strategy suggestions between the edge and interior of the fourth section of the Sinian series lamps in the Gaoshiti block

1.
Southern Sichuan Gas District of PetroChina Southwest Oil & Gasfield Company，Luzhou, Shichang 646200,China
2.
Research Institute of Exploration and Development, Southwest Oil & Gas Field Company, PetroChina, Luzhou, Shichang 646200,China

摘要

摘要: 安岳气田高石梯区块震旦系灯影组四段储层岩性复杂、非均质性强，台缘带和台内区单井产能差异大，生产效果也存在明显的差异。为实现台缘带灯四段气藏的长期稳产开发，台内区灯四段气藏高效建产。基于大量的地质、测井、气藏工程等资料，应用动静态相结合的方法全面剖析台缘带-台内区气藏共性及差异性特征，明确导致其差异性的控制因素。结果表明：① 台缘带与台内区储层岩石类型、储集空间及类型差异不大，但两者的储层发育规模、溶蚀孔洞发育程度、储层物性、渗流特征和气井生产特征存在差异性。② 有利丘滩沉积岩体的发育规模、表生岩溶作用和源储匹配程度是决定差异性的因素。③ 基于上述气藏的差异性认识，结合目前开发生产的需求形势，有针对性的提出了台缘带精细开发，实现持续稳产；台内区落实高产井模式和有利区分布，加快效益建产的开发建议。笔者提出的台缘带和台内区气藏差异性对比和主控因素分析的思路，为高石梯区块灯四气藏的有效开发，提供了科学开发的依据。
- 高石梯区块 /
- 台缘带 /
- 台内区 /
- 差异性 /
- 渗流特征
Abstract: The fourth section of Dengying Formation in the Gaoshiti block of the Anyue Gas Field is of complex lithology and strong heterogeneity. There is a significant difference in the single-well production capacity as well as in production efficiency between the platform margin and the intra-platform. To achieve long-term stable development of the gas reservoir in the fourth section of Dengying Formation at the platform margin, as well as efficient production of the corresponding section in the intra-platform, the controlling factors leading to the observed differences have been identified. This was accomplished through a combination of dynamic and static methods, which allowed for a comprehensive analysis of the common and distinct characteristics of the gas reservoirs in both the platform margin and intra-platform. This analysis was based on a substantial amount of geological, logging, gas reservoir engineering and other relevant data.The reservoir rock types and reservoir space in both the platform margin and the intra-platform share common characteristics. The lithology is primarily composed of doloarenite, algal-laminated dolomite, and algal-clotted dolomite. These rocks are all well developed in terms of dissolution pores. The porosity of the reservoir core ranges from 2.0% to 7.3%, with an average of 3.5%. The permeability ranges from 0.1 mD to 113 mD, with an average of 5.832 mD. The reservoir properties exhibit low porosity and low permeability, and the reservoir type is primarily characterized as fracture-pore (cave) type.However, there are differences between the platform margin and the intra-platform in terms of reservoir development scale, degree of dissolution pore development, reservoir physical properties, seepage characteristics, and characteristics of gas well production. At the platform margin, the proportion of wells with single-well test output larger than 500,000 cubic meters of gas is higher. The development degree of large pores and caves is greater, and the density of fracture development is also higher. In terms of production, the gas wells at the platform margin generally exhibit high and stable production, with an average daily gas production of 233,000 cubic meters per well. In contrast, the gas wells in the intra-platform show significant production differences, with a daily gas production of 145,000 cubic meters. In terms of seepage characteristics, the reservoir type at the platform margin is primarily classified as fracture-pore type, with fractures and fracture-cave systems serving as the main seepage channels. These wells exhibit relatively high test production rates and are capable of maintaining high and stable production.This paper comprehensively analyzes the reasons for the differences from four aspects, sedimentary environment, diagenesis, matching of reservoir conditions, and karst transformation. It clarifies that the sedimentary environment and reservoir conditions control the scale of reservoir development, while karst transformation in later stages plays a decisive role in the seepage characteristics and production differences of gas wells. The favorable shoal and lagoon bodies control the distribution of high-quality reservoirs, and the intensity of epigenetic karst transformation during the Tongwan Period determines the strength of dissolution and transformation. Additionally, the relationship between source and reservoir affects the efficiency of hydrocarbon migration and accumulation. Therefore, the development scale of shoal and lagoon deposits, the intensity of epigenetic karst transformation, and the source-reservoir relationship are the primary controlling factors determining the differences between the platform margin and the intra-platform.Based on a comprehensive comparison between the platform margin and the intra-platform, the former exhibits the thicker reservoir, superior physical properties, and dominant storage space types characterized by fracture-pore (cave) patterns. It also features a larger controlled radius, better fluid flow, a higher proportion of high-yield wells, and the potential for long-term, stable high production. In contrast, the intra-platform has the relatively thinner reservoir, comparable physical properties, and greater horizontal heterogeneity, resulting in more significant differences in the development of high-quality reservoirs. The production capacity of gas wells primarily comes from medium-and-low-yield wells, with a smaller proportion of wells capable of stable production. Given this comparison between the two zones and the production and development needs of the Gaoshiti block, the differentiated production suggestions are proposed. For the platform margin, the detailed characterization of high-quality seepage bodies within reservoir should be conducted, and the development of supplementary wells should be implemented to achieve stable production of gas reservoirs. For the intra-platform, the identification of favorable site distributions should be prioritized, and the production wells should be deployed to ensure efficient production.
- Gaoshiti area /
- platform margin belt /
- inner platform area /
- difference /
- transfusion characteristic

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图 1 四川盆地高石梯区块井位分布及地层综合柱状图

Figure 1. Distribution of well positions and comprehensive stratigraphic histogram in Gaoshiti block of Sichuan Basin

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图 2 台缘带—台内区储层特征基本情况

Figure 2. Basic information on reservoir characteristics in platform margin and inner platform area

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图 3 高石梯区块灯四气藏测试产量和无阻流量直方图

Figure 3. Test production and open flow histogram of Member 4 gas reservoir in Gaoshiti block

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图 4 台缘带测试产量饼图（35口井）

Figure 4. Production pie chart of platform margin (35 Wells)

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图 5 台内区测试产量饼图（20口井）

Figure 5. Production pie chart of inner platform area (20 wells)

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图 6 台缘带—台内区岩心储层孔洞发育比例直方图

Figure 6. Hole development ratio histogram of core reservoir in platform margin and inner platform area

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图 7 台缘带—台内区取心井段宏观裂缝密度直方图

Figure 7. Fracture density histogram of core reservoir in platform margin and inner platform area

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图 8 高石梯区块灯四段丘地比等值线图

Figure 8. Contour map of the Member 4 hill to ground ratio of the Gaoshiti block

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图 9 高石梯地区灯四段放空、井漏分布

Figure 9. Distribution of Member 4 emptying and well leakage in the Gaoshiti area

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表 1 台缘区和台内区生产井统计表

Table 1. Statistical table of production wells in platform margin and inner platform area

区块	投产井数/口	开井数/口	开井率/%	日产气/10⁴ m³	单井日产气/10⁴ m³	累产气/10⁸ m³
台缘区	35	35	100.00	814.98	23.29	98.01
台内区	9	4	44.44	58.18	14.54	2.24

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表 2 高石梯地区灯四气藏储层分类综合图版

Table 2. Comprehensive map of reservoir classification for Member 4 gas reservoir in Gaoshiti block

区带	储层类型	典型井	井型	试井曲线	井控半径/m	渗透率 /mD	渗流特征
台缘	裂缝—孔洞型	H27	水平井		400	4.47↑44.7	采用“水平井+径向复合”模型解释，井控半径大，远井区物性变好，反映储层物性变好，该井目前日产气54×10⁴ m³·d⁻¹，生产效果好
台缘	裂缝—孔洞型	X25	水平井		450	5.57↓0.51	采用“水平井+径向复合”模型解释，井控半径大，近井区存在高渗介质，渗透性较好，该井目前日产气60×10⁴ m³·d⁻¹，生产效果好
台内	孔洞型	103C1	水平井		160	0.54↓0.24	采用“水平井+无限大边界”模型解释，探测半径较近，远井区物性变差，该井目前日产气17×10⁴ m³·d⁻¹，生产效果较稳定
台内	孔隙型	G10	水平井		50	0.02↑0.08	采用“无限导流+复合”模型解释，探测半径较近，整体物性较差，该井目前日产气仅5×10⁴ m³·d⁻¹，生产效果一般

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