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Recent exploration has revealed that the Middle Triassic Leikoupo Formation 32 Submember (T2/32) in the Sichuan Basin contains unconventional marl reservoirs with significant natural gas potential. Due to limited cores, old wells, and conventional logs, however, the lithological understanding of T2/32 is incomplete and relies solely on inaccurate mud logs. This lack of lithological foundation challenges geology and petroleum research. To identify complex lithology, this paper presents a double-hierarchical workflow to identify seven types of lithology using logs. The first order distinguishes salt, anhydrite, and marl, while the second order further subdivides marl into anhydrite marl, argillaceous limestone, shaly limestone, and limy shale. Different rocks' logging response characteristics are summarized based on quantity-limited cores and micro-resistivity imaging logs. Lithological identification of 2D and 3D plots is established using sensitive GR, DEN, and RT. Corresponding identification standards are built in two hierarchies. According to these standards, the lithology of T2/32 is identified in a total of 119 wells. Finally, the lithological characteristics of vertical, horizontal, and plane are discussed in the research area. The research results may aid in comprehending the entire lithological characteristics of the complex marl reservoir in T2/32 of the Sichuan Basin. It would help the exploration potential of petroleum systems in turn. [ABSTRACT FROM AUTHOR]

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The exploration and comprehensive assessment of fractured-vuggy reservoir information have perennially constituted focal points and challenges within the domain of oil and gas reservoir evaluation. The verification of geological phenomena, identification of various fracture and hole types, and the quantitative characterization thereof currently present pressing challenges. This study meticulously examines the deep carbonate reservoirs within the Dengying Formation in the Penglai gas region of the Sichuan Basin. The Core Rolling Scan images reveal five discernible features: unfilled holes, filled holes, filled fractures, open fractures, and algae. The analysis pinpoints three primary challenges in semantic segmentation recognition: the amalgamation of feature scales, class imbalance, and the scarcity of datasets with substantial sample sizes. To address these challenges, this paper introduces a Multi-Scale Feature Aggregation Pyramid Network model (MFAPNet), achieving a pixel accuracy of 68.04% in recognizing the aforementioned five types. Lastly, the model is employed in calculating core porosity, exposing a scaling relationship between wellbore image porosity and core porosity ranging from 1.5 to 3 times. To a certain extent, it reveals the correlation between the wellbore image logging data and the actual formation of the Dengying Formation in the Penglai Gas Field of the Sichuan Basin, and also provides a basis for the subsequent logging evaluation of the formation. The partial code and CHA355 dataset are publicly available at https://github.com/zyng886/MFAPNet. [ABSTRACT FROM AUTHOR]

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Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

The central Sichuan Basin, located in western China, holds great significance in terms of hydrocarbon production, especially in relation to complex carbonate reservoirs, notably the Qixia Formation of the Middle Permian epoch. However, the comprehensive evaluation of this geological formation presents considerable challenges due to complex lithology, limited availability of reservoir property data at various scales, inadequacies in data integration, and the absence of a reliable reservoir ranking system for development decision making. Previous studies primarily relying on conventional data at the reservoir level, such as well logs and geological information, have proven insufficient in accurately characterizing the reservoir. This is especially evident without precise lithological information and detailed knowledge of microscale properties, which are crucial for effective reservoir evaluation. To address these challenges, this study integrates advanced technologies like X-ray diffraction, micro-CT and scanning electron microscope (SEM) techniques in digital drill cutting analysis at the microscale. A novel scoring system has been developed using a prominent component analysis (PCA) approach and an expert scoring system, which incorporates existing conventional well log data and digital cutting analysis. This scoring system has been validated using actual production data, thus establishing a robust evaluation methodology for assessing the exploration potential and optimizing development strategies for carbonate gas reservoirs in the Qixia Formation. The innovative approach, which incorporates parameters at both micro- and macroscales, holds promising potential in facilitating future exploration and development efforts. [ABSTRACT FROM AUTHOR]

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Located in the Sichuan Basin of China, the central Sichuan paleo-uplift is a geological structure that spanned several areas in Sichuan province and was formed 500 million years ago. It is the bottom layer with rich conventional natural gas resources of more than 3 × 10 12 m 3 , and the proven reserves are about 30%, while the recovery rate is only 1.4%. In this paper, the Hubbert and Gauss models are used to study the peak production of natural gas. The Monte Carlo simulation method is used to predict the realization probability of future medium and long-term production, evaluate the risk level of natural gas production, and realize the whole process research from scale prediction to risk quantification of gas reservoirs. According to the Gauss model, under the realization probability of P50, the gas reservoir in the central Sichuan paleo-uplift can reach a peak production value of 145 × 10 8 m 3 / a , in 2040, and maintain a stable production state in 2034-2046. The risk grade evaluation matrix, through which the dispersion degree C ∈ (5% and 10%) in the rising stage and rapid production decline stage can be obtained, and the dispersion degree C ∈ (10% and 25%) in the stable production stage and slow production decline stage can be obtained. The dispersion degree and realization probability can be integrated to obtain the risk level at different stages. [ABSTRACT FROM AUTHOR]

The shale gas exploration in Changning, Weiyuan, Fuling Jiaoshiba, and other areas has achieved great success in the Sichuan Basin, and the basin margin of the Sichuan Basin will be an important target in the future. In view of the lack of understanding of shale gas reservoir characteristics of the basin margin area of the Sichuan Basin, this paper conducts a study on reservoir characteristics and gas-bearing properties of this area using qualitative and quantitative techniques. The results show that the thickness of the black shale reservoir in the Qianjiang area is up to 33 m, the kerogen sapropelic type (I) is dominant, and Ro ranges from 2.2 wt% to 3.39 wt%. The mineral composition is relatively complex, mainly composed of quartz and clay minerals. Quartz content is in the range between 9.4 wt% and 79 wt% (average = 47.48 wt %), while clay content is in the range between 10.02 wt% and 43.6 wt% (average = 29.41 wt %). There are various types of reservoir spaces, mainly including organic pores dominated by matrix pores, intergranular and intragranular pores, intergranular and intragranular dissolution pores, secondary dissolution pores, and microfractures, among which organic pores are the main pore types. The pore volume of nanopores is 0.009897-0.017177 cm3/g (average = 0.01304 c m 3 / g), and the specific surface area ranges from 12.1 m2/g to 35.1 m2/g (average = 20.47 m 2 / g). Micropores and mesopores are the main pore sizes for the development of organic pores. Quartz particles promote the development of reservoir space, while clay minerals are not conducive to the development of pores. The total gas content ranges from 0.5 m3/t to 4.43 m3/t (average = 1.69 m 3 / t). Its enrichment is controlled by many factors. The increase of organic matter abundance is the material basis for shale gas enrichment. The development of organic pores provides high-quality storage space for shale gas preservation. The development of different mineral components restricts the enrichment of shale gas. [ABSTRACT FROM AUTHOR]

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Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

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Carbonate gas reservoirs in the Sichuan Basin have many complex characteristics, such as wide distribution, strong heterogeneity, high temperature, high pressure, high H2S and CO2 content and an active edge or bottom water. In the late stage of exploitation of carbonate sour gas reservoirs, the underground depleted reservoirs can provide a broad and favorable space for CO2 storage. If CO2 is injected into the depleted carbonate sour reservoirs for storage, it will help to achieve the goal of carbon neutrality, and the CO2 stored underground can perform as "cushion gas" to prevent the advance of edge or bottom water, to achieve the purpose of enhanced natural gas recovery. Injecting CO2 into low permeability reservoirs for oil displacement has become an important means to enhance oil recovery (EOR). However, the mechanism of EOR by injecting CO2 into carbonate sour gas reservoirs is not clear and the related fundamental research and field application technology are still in the exploration stage. This paper reviews the main scientific and technical perspectives in the process of injecting CO2 into carbonate sour gas reservoirs for storage and enhancing gas recovery. [ABSTRACT FROM AUTHOR]

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Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Clarifying the gas–water distribution of gas reservoirs can effectively develop water-bearing gas reservoirs and form water control schemes. The Longwangmiao Formation gas reservoir in MX gas field in Sichuan Basin (hereinafter referred to as “Longwangmiao Reservoirs”) is a large-scale gas reservoir with low and gentle structure. The current production dynamics have proved that the early understanding of uniform gas–water interface and water invasion does not reflect the reality. The special and complex storage mode and water invasion characteristics of the formation water requires detailed and accurate descriptions of the gas–water relationship and the water invasion behavior of gas reservoirs. This paper first defines the storage mode of how the formation water structures the main area of the gas reservoirs where the edge water and locally sealed water coexist the main control factors. Based on the comprehensive interpretation of oil test and logging, this paper discusses the relationship between the water saturation in water and the structural elevation of the structure to establish a water saturation-gas column height model, thus defining the optimal gas–water interface of the gas reservoirs with refined and accurate description of the original gas– water distribution pattern of gas reservoirs. This paper also reveals the water invasion behavior and the dynamic change pattern of gas–water distribution by combining the seepage-capacity-based reservoir distribution pattern with the dynamic production characteristics. The study shows that: (1) the original gas–water interface s of the gas reservoirs are not unified. The north wing of the main area is rather consistent with a changing range of –4,385 ± 3 m, while the southern wing varies greatly with a range of –4,390 ~ –4,410 m due to the influence of dip angle and water energy; (2) The Longwangmiao Reservoirs can be classified into three categories according to seepage capacity which are heterogeneous; (3) Influenced by multiple factors such as structure, lithology, pore throat structure, degree of fracture development and coexistence of various formation water storage modes, the gas–water interface does not advance uniformly and evenly during the development, while the water in the main area advances rapidly along the high permeability zone and the fracture development area of Type I reservoir. [ABSTRACT FROM AUTHOR]

This paper summarizes the latest progress of variable viscosity slick water technology in China, analyzes the application of variable viscosity slick water in unconventional gas reservoirs in Sichuan and Chongqing, and puts forward the development direction of variable viscosity slick water. The variable viscosity slick water realizes the real-time switching of low, medium and high viscosity liquids by adjusting the concentration of drag reducer and / or introducing cross-linking agent. The research of drag reducer focuses on the synthesis and performance evaluation of polyacrylamide containing AMPS or SSS salt-tolerant groups and hydrophobic associating polymer, to meet the needs of preparing fracturing flow-back fluid mixing and change viscosity. The research on the performance of variable viscosity slick water mainly focuses on the influence law of viscosity on sand carrying performance, fracture morphology and drag reduction performance, but it is not yet determined what viscosity is suitable for what reservoir. The application of variable viscosity slick water in unconventional gas reservoirs in Sichuan and Chongqing was successful. The overall viscosity in tight gas is higher than that in shale gas, and the sand carrying capacity in deep shale gas needs to be further enhanced. Hydrophobically associating polymer drag reducer and solid drag reducer are the development direction of variable viscosity slick water. It is expected to solve the problems of high frictional resistance of high viscosity liquid and potential environmental risks of emulsion drag reducer. This paper has certain guiding significance for the research and application of variable viscosity slick water. [ABSTRACT FROM AUTHOR]

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The Jurassic continental shale oil (gas) is a favorable unconventional resource in the Sichuan Basin of China. In this paper, analysis methods such as core and outcrops observation, thin section identification, scanning electron microscopy (SEM), and X-ray diffraction (XRD) are used to describe the characteristics of lacustrine fine-grained rock reservoir in Da'anzhai Member of the Ziliujing Formation in Sichuan Basin, and it discussed the influence and control of lacustrine fine-grained rock diagenesis on the quality of the reservoir, in order to determine the shale reservoir control factors. The results show that there are three types of rocks in the Da'anzhai Member, which are mudstone, siltstone, and limestone, and the rock combination of shell shale intercalated with shell limestone is developed in the Da 2 submember. Fine-grained sedimentary rocks in this section have undergone compaction, cementation, dissolution, metasomatism, transformation of clay minerals, and hydrocarbon generation of organic matter, which are currently in the middle diagenetic stage A or B substage. Compaction and cementation are the main factors that control the physical use of shale and limestone, and strong cementation is the main reason for the tightness of limestone reservoirs in the Da'anzhai Member in the northern and eastern parts of Sichuan Basin. The difference between dissolution and cementation is the main control factor for the formation of limestone or argillaceous limestone reservoirs in the same section in central Sichuan Basin. The organic-rich shale and shell shale of the Yuanba and Fuling area are the most favorable reservoirs of the Ziliujing Formation in this region. The shell limestone that experienced favorable dissolution in the Da'anzhai Member in the central of the Sichuan Basin has become a limestone reservoir. Discussing the impact of continental fine-grained rock diagenesis on the reservoir can better explore and develop similar intervals, enrich unconventional shale oil and gas accumulation and storage theories, and provide basic theoretical support for finding favorable unconventional shale oil and gas reservoirs. [ABSTRACT FROM AUTHOR]

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Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Copyright of Natural Gas Geoscience is the property of Natural Gas Geoscience and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Cracks and pores coexist in carbonate reservoirs, and this complex pore structure has a significant impact on acoustic and resistivity logging. Making full use of acoustic and electrical well logging data can help to identify carbonate gas reservoirs. First, this paper studies the controlling effects of different lithologies on the acoustic velocity according to the elastic theory of porous and fractured media based on joint acoustic-resistivity rock physics measurement experiments. At the same time, a theoretical gas-bearing reservoir identification template is established based on acoustic experimental data, and the gas-bearing reservoir identification template is used to qualitatively identify a gas reservoir. Then, the empirical relationship between the acoustic velocity and resistivity is derived based on the Archie equation. It is found that the formation P-wave velocity and resistivity have a power function relationship in the research area. Based on the above research, a quantitative identification template for gas-bearing reservoirs is established. The case study has verified the reliability of the gas-bearing carbonate reservoir identification method based on the above two methods. [ABSTRACT FROM AUTHOR]

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Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

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Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Copyright of Natural Gas Industry is the property of Natural Gas Industry Journal Agency and its content may not be copied or emailed to multiple sites or posted to a listserv without the copyright holder's express written permission. However, users may print, download, or email articles for individual use. This abstract may be abridged. No warranty is given about the accuracy of the copy. Users should refer to the original published version of the material for the full abstract. (Copyright applies to all Abstracts.)

Multi-component seismic exploration is an important technique in the utilization of P-waves and converted S-waves for oil and gas exploration. It has unique advantages in the structural imaging of gas zones, reservoir prediction, lithology, and gas-water identification, and the development direction and degree of fractures. Multi-component joint inversion is one of the most important steps in multi-component exploration. In this paper, starting from the basic principle of multi-component joint inversion, the differences between the method and single P-wave inversion are introduced. Next, the technique is applied to the PLN area of the Sichuan Basin, and the P-wave impedance, S-wave impedance, and density are obtained based on multi-component joint inversion. Through the velocity and lithology, porosity, and gas saturation fitting formulas, prediction results are calculated, and the results are analyzed. Finally, multi-component joint inversion and single P-wave inversion are compared in effective reservoir prediction. The results show that multi-component joint inversion increases the constraints on the inversion conditions, reduces the multi-solution of a single P-wave inversion, and is more objective and reliable for the identification of reservoirs, effectively improving the accuracy of oil and gas reservoir prediction and development. [ABSTRACT FROM AUTHOR]