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Petrological and Geochemical Characteristics of Reservoirs

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A special issue of Minerals (ISSN 2075-163X). This special issue belongs to the section "Mineral Geochemistry and Geochronology".

Deadline for manuscript submissions: 15 March 2025 | Viewed by 7462

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Prof. Dr. Tivadar M. Tóth

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Department of Mineralogy, Geochemistry and Petrology, University of Szeged, 6702 Szeged, Hungary
Interests: petrology; structural geology; numerical simulation of fractured fluid reservoirs
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Dr. Yubin Bai

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School of Earth Sciences and Engineering, Xi'an Shiyou University, Xi'an, 710065 China
Interests: petroleum geology; organic geochemistry, shale oil mobility evaluation
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Dear Colleagues,

Most rock bodies with applied geological importance can be evaluated from the point of fluid storage and conduit capacities. Some of these rock masses are real fluid reservoirs that store hydrocarbons, geothermal energy, and drinking water or contain ores available for in situ leaching technology. Concerning productivity, the most significant parameters of these rock bodies are sufficient porosity and permeability. In other cases, like radioactive waste depositories, the rock body is hoped to be of low porosity and permeability and so free of significant fluid migration. Nevertheless, these bodies also store water that interacts with the host rock, modifying its mineral composition and mechanical features and so affecting the depository's safety.

Although, in all the above examples, the hydrodynamic behaviour of the rock body is essential, it is usually determined by the petrological characteristics of the rock mass in question. In most sedimentary sequences, primary (intergranular) porosity and permeability are the function of the combined effect of numerous syn- and post-sedimentary processes, like all steps of the diagenesis (dissolution of the detrital grains, physical and chemical compaction, cementation, etc.) that may significantly modify the primary hydrodynamic features. Igneous and metamorphic rock bodies usually have negligible matrix porosity and therefore act as fractured reservoirs. Such fracture networks may occur as mutually interconnected or even may define isolated clusters of unconnected fracture sets, depending on the petrological (including mineralogy, fabric, structure, etc.) circumstances in the same stress field. Consequently, blocks with significantly different reservoir qualities usually occur close to each other in a heterogeneous rock body, making the reservoir's hydrodynamics highly complicated. Double porosity systems, in which primary and secondary cavities interact (e.g., karstified and fractured limestone bodies), may be even more complex.

In this Special Issue, we kindly invite manuscripts that focus on case studies or methodological approaches in the following or similar topics:

How do petrological circumstances determine the hydrodynamic behaviour of fluid reservoirs in different rock bodies?
How do petrological features determine the rock mechanical behaviour of rock bodies while natural and artificial fractures develop?
What is the role of mineralogical composition in fluid–rock interaction processes that modify reservoir qualities through dissolution and cementation (including vein cementation)?
What is the role of rock chemistry in scale formation?

Prof. Dr. Tivadar M. Tóth
Dr. Yubin Bai
Guest Editors

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Keywords

buried hill reservoir
igneous and metamorphic reservoirs
water–rock interaction
petrological heterogeneity
in situ leaching mining
scale formation

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Published Papers (6 papers)

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Research

22 pages, 11544 KiB

Open AccessArticle

Sandstone Porosity Evolution and Reservoir Formation Models of the Paleogene Huagang Formation in Yuquan Structure of West Lake Sag, East China Sea Basin

by Yonghuang Cai, Zhengxiang Lv, Yuanhua Qing, Cheng Xie, Bingjie Cheng, Zheyuan Liao and Bing Xu

Minerals 2024, 14(9), 899; https://doi.org/10.3390/min14090899 - 31 Aug 2024

Viewed by 693

Abstract

The West Lake Sag is abundant in oil and gas reserves, primarily in the Huagang Formation reservoir which serves as the primary source of production. The level of exploration is rather high, but there are still some unresolved issues, such as an unclear understanding of pore evolution features and reservoir growth mode. To tackle the aforementioned problems, this study employs optical microscopic examination, scanning electron microscope analysis, inclusion analysis, isotope analysis, X-ray diffraction analysis, and other techniques to elucidate the primary factors governing reservoir development and establish an analytical model regarding the cause of the sandstone reservoir. The results are as follows: (1) The sandstone reservoirs of the Huagang Formation of the Yuquan (abbreviated to YQ) Structure are now in the mesomorphic A stage as a whole, and minerals such as 4-phase authigenic quartz, 2-phase illite, 2-phase chlorite, 1-phase kaolinite, 1-phase ammonite mixing layer and 2-phase carbonate were formed during the diagenesis. (2) Feldspar and carbonate solution pores make up the majority of the reservoir space. About 10% of the porosity is made up of carbonate solution pores, which are the most prevalent reservoir space. Carbonate solution pores are primarily made up of metasomatic carbonate solution pores and cemented carbonate solution pores. Feldspar solution pores come next, contributing roughly 6.2% of the porosity. At 1.8%, residual intergranular holes are the least common. (3) The four main processes listed below are responsible for the creation of pores in the sandstone of the Huagang creation. The early carbonate cements resist the destruction of mechanical compaction and effectively preserve intergranular volume. The high content of feldspar provided a material basis for later dissolution. Early chlorite surrounding the edges of particles reduced the damage of authigenic minerals to porosity. The faults and cracks formed by the later structural inversion connected to the acidic water in the atmosphere, causing the dissolution of carbonate minerals and feldspar in the sandstone of the Huagang Formation. (4) Carbonate dissolution + feldspar dissolution type, carbonate dissolution type, and feldspar dissolution type are the three main types of reservoir formation in the Huagang Formation; the first two types mainly develop in the Upper Huagang Formation, while the latter mainly develops in the lower part of the Huagang Formation. The research results are conducive to the establishment of a geological prediction model for high-quality reservoirs of different geneses in the Huagang Formation and promote the exploration process of deep-seated hydrocarbons in the West Lake Sag. Full article

(This article belongs to the Special Issue Petrological and Geochemical Characteristics of Reservoirs)

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25 pages, 14510 KiB

Open AccessArticle

Genesis of Analcite in Black Shales and Its Indication for Hydrocarbon Enrichment—A Case Study of the Permian Pingdiquan Formation in the Junggar Basin, Xinjiang, China

by Yang Bai, Xin Jiao, Yiqun Liu, Xu Li, Xu Zhang and Zhexuan Li

Minerals 2024, 14(8), 810; https://doi.org/10.3390/min14080810 - 10 Aug 2024

Viewed by 1115

Abstract

This study investigates the genesis of analcite in black shale from continental lakes and its implications for hydrocarbon enrichment, with a case study of the Permian Pingdiquan Formation in the Junggar Basin, Xinjiang, China. As an alkaline mineral, analcite is extensively developed in China’s lacustrine black shale hydrocarbon source rocks and is linked to hydrocarbon distribution. However, the mechanisms of its formation and its impact on hydrocarbon generation and accumulation remain insufficiently understood. This paper employs a multi-analytical approach, including petrological observations, geochemical analysis, and X-ray diffraction, to characterize analcite and its association with hydrocarbon source rocks. The study identifies a hydrothermal sedimentary origin for analcite, suggesting that it forms under conditions of alkaline lake water and volcanic activity, which are conducive to organic matter enrichment. The analcite content in the studied samples exhibits a significant variation, with higher contents associated with hydrocarbon accumulation zones, suggesting its role in hydrocarbon generation and accumulation. This paper reports that analcite-bearing rocks display characteristics of high-quality reservoirs, enhancing the permeability and porosity of the rock, which is essential for hydrocarbon storage and migration. In conclusion, this paper underscores the importance of analcite as a key mineral indicator for hydrocarbon potential in black shale formations and provides valuable insights for further geological and hydrocarbon exploration in similar settings. Full article

(This article belongs to the Special Issue Petrological and Geochemical Characteristics of Reservoirs)

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27 pages, 10704 KiB

Open AccessArticle

A Genetic Mechanism for Chemical Compaction in Mudstones: Case Study from the Xihu Depression, East China Sea Shelf Basin

by Zilong Zhao, Jingzhou Zhao, Hong Zhao, Jun Wang, Chuang Er, Zhe Li and Shixiong Wang

Minerals 2024, 14(4), 413; https://doi.org/10.3390/min14040413 - 17 Apr 2024

Viewed by 1018

Abstract

Mudstone compaction is widely used in the estimation of subsidence caused by sediment load, basin modeling, and overpressure genesis. The boundary for the depth at which chemical compaction in mudstones begins in the Xihu Depression is across two wells; in Well A, the depth is 2200 m, while in Well D, it is 1750 m. The porosity shows a gradual decreasing trend, followed by a sharp decrease and then an increase. Compared with Well A, the pores in Well D show a faster reduction (resulting in higher compaction) with increasing burial depth. The compaction process is controlled by clay mineral transformation and temperature increase. At a temperature range of 65–105 °C, local dissolution of quartz and pyrite, as well as precipitation of plagioclase, occur in Well D. The quartz, pyrite, and plagioclase contents in Well A do not significantly change, while K-feldspar corrosion and illitization are dominant. At a temperature range of 125–135 °C, diagenesis is reversed. The mixed layer increases across a low range, while chlorite and kaolinite contents increase; the dissolution of dolomite and the intermittent dissolution of calcite cause a local increase in pore size at 4460 m in Well A and 3300 m in Well D. The report values of geothermal gradient raise the depth limit of chemical compaction in Well D compared to that in Well A, thus accelerating the process of illitization and the cementation rate of quartz, and becoming the leading cause of the steeply decreasing trend of porosity in Well D. A compaction model for the Xihu Depression has also been established, which involves mechanical compaction, coexistence of chemical compaction and mechanical compaction, and chemical compaction. In the chemical compaction stage, the chemical/diagenetic compaction of mudstones locally increases the pore size. Moreover, abnormally enlarged pores became important reservoirs in the Xihu Depression. Full article

(This article belongs to the Special Issue Petrological and Geochemical Characteristics of Reservoirs)

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31 pages, 56008 KiB

Open AccessArticle

Fracture Density Prediction of Basement Metamorphic Rocks Using Gene Expression Programming

by Muhammad Luqman Hasan and Tivadar M. Tóth

Minerals 2024, 14(4), 366; https://doi.org/10.3390/min14040366 - 29 Mar 2024

Cited by 1 | Viewed by 1097

Abstract

Many methods have been developed to detect and predict the fracture properties of fractured rocks. The standard data sources for fracture evaluations are image logs and core samples. However, many wells do not have these data, especially for old wells. Furthermore, operating both methods can be costly, and, sometimes, the data gathered are of bad quality. Therefore, previous research attempted to evaluate fractures indirectly using the widely available conventional well-logs. Sedimentary rocks are widespread and have been studied in the literature. However, fractured reservoirs, like igneous and metamorphic rock bodies, may also be vital since they provide fluid migration pathways and can store some hydrocarbons. Hence, two fractured metamorphic rock bodies are studied in this study to evaluate any difference in fracture responses on well-log properties. Also, a quick and reliable prediction method is studied to predict fracture density (FD) in the case of the unavailability of image logs and core samples. Gene expression programming (GEP) was chosen for this study to predict FD, and ten conventional well-log data were used as input variables. The model produced by GEP was good, with R2 values at least above 0.84 for all studied wells, and the model was then applied to wells without image logs. Both selected metamorphic rocks showed similar results in which the significant parameters to predict FD were the spectral gamma ray, resistivity, and porosity logs. This study also proposed a validation method to ensure that the FD value predictions were consistent using discriminant function analysis. In conclusion, the GEP method is reliable and could be used for FD predictions for basement metamorphic rocks. Full article

(This article belongs to the Special Issue Petrological and Geochemical Characteristics of Reservoirs)

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17 pages, 7521 KiB

Open AccessArticle

Reservoir Characterization of Alluvial Glutenite in the Guantao Formation, Bohai Bay Basin, East China

by Qing Li, Xuelian You, Yuan Zhou, Yu He, Renzhi Tang and Jiangshan Li

Minerals 2024, 14(3), 317; https://doi.org/10.3390/min14030317 - 16 Mar 2024

Viewed by 1221

Abstract

Alluvial glutenite reservoirs have obviously stronger heterogeneous and more complex control factors than sandstone reservoirs. Taking the Binxian Uplift area in the Boahi Bay Basin as an example, the aim of this study is to clarify the characteristics and control factors of the alluvial glutenite reservoir quality and the influence of reservoir properties on hydrocarbon accumulation. Pore types in the study area mainly include residual intergranular pores, intergranular dissolved pores, intragranular dissolved pores, and mold pores. The residual intergranular pores and intergranular dissolved pores are the main pore types. Most samples have porosity greater than 15% and permeability is mainly concentrated between 50 mD and 500 mD. It is shown that lithology type, microfacies, and diagenesis have significant impact on the reservoir quality. The reservoir qualities of very fine sandstone and fine sandstone are better than those of conglomerate and gravel-bearing sandstone. Instead of grain size, sorting affects the alluvial glutenite reservoir quality significantly. Oil-bearing samples commonly have sorting coefficient less than 2 while non-oil-bearing samples have sorting coefficient larger than 2. There are significant differences in reservoir physical properties of different sedimentary microfacies. The stream flow in mid-alluvial fan (SFMA) and braided channels outside alluvial fans (BCOA) have relatively weaker compaction and better reservoir quality than the overflow sand body (OFSB) and debris-flow in proximal alluvial fan (DFPA). Calcite cementation, the main cement in the study area, commonly developed at the base of SFMA and BCOA and near the sandstone-mudrock contacts. The source of calcium carbonate for calcite cement mainly came from around mudstone. High calcite cement content commonly results in low porosity and permeability. Individual glutenite thickness is also an important influencing factor on reservoir quality. Reservoirs with large thickness (>4 m) have high porosity and permeability. Dissolution occurred in the reservoir, forming secondary dissolution pores and improving reservoir quality. The dissolution fluid for formation of secondary pores is mainly meteoric waters instead of organic acid. The reservoir property has an important influence on hydrocarbon accumulation. The lower limit of physical properties of an effective reservoir is a porosity of 27% and permeability of 225 mD. The findings of this study can be utilized to predict the reservoir quality of alluvial glutenite reservoirs effectively in the Bohai Bay Basin and other similar basins. Full article

(This article belongs to the Special Issue Petrological and Geochemical Characteristics of Reservoirs)

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18 pages, 9861 KiB

Open AccessArticle

Characteristics and Controlling Factors of Particle Crushing in Volcaniclastic Sediments under Compaction: The Quaternary Pyroclastic Deposits of Hongtu Hill, Changbaishan Area, Northeastern China

by Jiawei Bai, Huafeng Tang, Jia Hu, Liying Yang, Tianchan Guo and Zhiqiang Zhang

Minerals 2023, 13(10), 1351; https://doi.org/10.3390/min13101351 - 23 Oct 2023

Cited by 1 | Viewed by 1472

Abstract

Recently, many scholars have conducted experimental mechanical compaction studies on sandstones, carbonates, and mudstones to visually study the mechanical compaction process and reservoir evolution of sedimentary rocks. However, experimental mechanical compaction studies on the evolution of the compaction process of pyroclastic rocks have been ignored. Volcaniclastic rock reservoirs are widely distributed across the world and strongly influenced by the crushing of pyroclastic particles. In this study, we analyzed the characteristics and controlling factors of the crushing of pyroclastic particles during compaction diagenesis from a microscopic perspective through experimental mechanical compaction. These results can provide quantitative compaction background parameters for the quantitative study of pyroclastic rock reservoir evolution. We took pyroclastic samples from Hongtu Hill in the Changbaishan area as an example, and experimental mechanical compaction experiments were conducted. Furthermore, image surface porosity and particle analysis statistical methods were used, and the variations in the effective porosity and image surface porosity under different axial stresses were studied. The results showed that, after compaction, the effective porosity did not exhibit a decreasing trend with increasing axial stress but rather a normal distribution trend that initially increased and then decreased. In the compaction experiment, the pyroclastic particle crushing process was segmented with increasing axial stress, and there was an obvious compaction band in the initial stage of the compaction, called the particle rearrangement stage (10–30 MPa). Furthermore, there were relatively non-successive compaction localization areas in the later stage of compaction, called the particle crushing stage (50–70 MPa), which was represented by vitreous basalt particles surrounded by porphyritic basalt particles. During experimental mechanical compaction, the smaller the compactness, the smaller the solidity, and the larger the slenderness of the particles, the more likely the particles were to break during compaction. Particles containing intragranular pores and vitreous basalt particles were easily crushed. Full article

(This article belongs to the Special Issue Petrological and Geochemical Characteristics of Reservoirs)

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