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Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources

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A special issue of Energies (ISSN 1996-1073). This special issue belongs to the section "H1: Petroleum Engineering".

Deadline for manuscript submissions: closed (30 October 2023) | Viewed by 16306

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Dr. Weiming Wang

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School of Geosciences, China University of Petroleum (East China), Qingdao 266580, China
Interests: comprehensive evaluation of tight oil and gas geology; oil and gas migration and accumulation and accumulation
Special Issues, Collections and Topics in MDPI journals

Dr. Xiyu Qu

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School of Geosciences, China University of Petroleum (East China), Qingdao 266580, China
Interests: evaluation of tight reservoir
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Prof. Dr. Jijun Li

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School of Geosciences, China University of Petroleum (East China), Qingdao 266580, China
Interests: evaluation of tight and shale oil enrichment and recovery
Special Issues, Collections and Topics in MDPI journals

Dr. Xiaobo Guo

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School of Earth Sciences and Engineering, Xi’an Shiyou University, Xi’an 710065, China
Interests: geological evaluation of tight oil and gas; continental shale oil and gas; mechanism of hydrocarbon accumulation

Prof. Dr. Hongqi Yuan

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School of Geosciences, Northeast Petroleum University, Daqing 163318, China
Interests: comprehensive evaluation of tight oil and gas geology; oil and gas migration and accumulation and accumulation; reservoir evaluation of shale oil; sequence stratigraphy; sedimentary facies analysis; reservoir evaluation of volcanic oil
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

Compared with other types of unconventional oil and gas resources, tight oil and gas reservoirs have better seepage and fracturing properties and are a more realistic choice for increasing reserves and production in the global unconventional oil and gas fields. The exploration and development of tight oil and gas resources are in a golden period of rapid development after undergoing a theoretical and technical preparation period and a policy promotion period. With improvements in tight oil and gas evaluation methods and testing methods, tight oil and gas exploration has seen great progress in many aspects, such as effective source rock evaluation, reservoir evaluation, and accumulation mechanism.

The purpose of this Special Issue is to display and publicize the test characterization methods, research methods, and recent research progress in the field of tight oil and gas geological evaluation.

Topics include but are not limited to:

The latest test methods for tight oil and gas;
Sedimentary and geochemical characteristics of tight oil and gas;
Evaluation of tight oil and gas effective source rocks;
Characterization and evaluation of tight oil and gas reservoirs;
Occurrence mechanism and accumulation law of tight oil and gas;
Comprehensive evaluation and exploration technology of tight oil and gas sweet spots.

Dr. Weiming Wang
Dr. Xiyu Qu
Prof. Dr. Jijun Li
Dr. Xiaobo Guo
Prof. Dr. Hongqi Yuan
Guest Editors

Manuscript Submission Information

Manuscripts should be submitted online at www.mdpi.com by registering and logging in to this website. Once you are registered, click here to go to the submission form. Manuscripts can be submitted until the deadline. All submissions that pass pre-check are peer-reviewed. Accepted papers will be published continuously in the journal (as soon as accepted) and will be listed together on the special issue website. Research articles, review articles as well as short communications are invited. For planned papers, a title and short abstract (about 100 words) can be sent to the Editorial Office for announcement on this website.

Submitted manuscripts should not have been published previously, nor be under consideration for publication elsewhere (except conference proceedings papers). All manuscripts are thoroughly refereed through a single-blind peer-review process. A guide for authors and other relevant information for submission of manuscripts is available on the Instructions for Authors page. Energies is an international peer-reviewed open access semimonthly journal published by MDPI.

Please visit the Instructions for Authors page before submitting a manuscript. The Article Processing Charge (APC) for publication in this open access journal is 2600 CHF (Swiss Francs). Submitted papers should be well formatted and use good English. Authors may use MDPI's English editing service prior to publication or during author revisions.

Keywords

geological evaluation of tight oil
geological evaluation of tight gas
tight reservoir evaluation
tight hydrocarbon accumulation mechanism
tight oil and gas prediction
tight reservoir evaluation technology

Related Special Issue

Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources: 2nd Edition in Energies

Published Papers (11 papers)

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Research

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20 pages, 6476 KiB

Open AccessArticle

Tight Sandstone Reservoir Characteristics and Controlling Factors: Outcrops of the Shanxi Formation, Liujiang River Basin, North China

by Tianqi Zhou, Hongqi Yuan, Fengming Xu and Rigen Wu

Energies 2023, 16(10), 4127; https://doi.org/10.3390/en16104127 - 16 May 2023

Cited by 2 | Viewed by 1148

Abstract

Tight sandstone reservoirs are of interest due to their potentially favorable prospects for hydrocarbon exploration. A better understanding of tight sandstone outcrop reservoir characteristics and their influencing factors is thus needed. By laboratory observation, thin section analysis, and experimental analysis, the current work carried out a detailed investigation of densely sampled tight sandstone outcrops of the Shanxi Formation in the Liujiang River Basin, paving the way for further research on rock types, reservoir spatial distribution, physical properties, and their key controlling factors. The application of the Pressure Pulse Attenuation Method made it possible to determine the porosity and permeability, as well as the analysis of debris composition and filling content. The findings indicate that the main rock type of the tight sandstone outcrop reservoirs in the Shanxi Formation in the Liujiang River Basin is lithic quartz sandstone, some of which contains fine sand-bearing argillaceous siltstone, giving them very low porosity (average porosity of 4.34%) and low permeability (average permeability of 0.023 mD) reservoirs. Secondary pores—mostly dissolved pores among and in grains—are widely developed in the target region. In addition, diagenesis primarily includes mechanical compaction, cementation, and dissolution. The main controlling factors of tight sandstone reservoirs in the target region are sedimentation, diagenesis, and tectonics, whereby sedimentation affects reservoir physical properties that become better as the clast size increases, reservoir properties are negatively impacted by compaction and cementation, and reservoir properties are somewhat improved due to dissolution and the impact of tectonism. In addition, the tilt of the crust will produce faults during the tectonic action, generating reservoir cracks that improve the reservoir’s physical properties. This study tends to be helpful in the prediction of high-quality reservoirs in the Permian Shanxi Formation in North China and can also be used for analogy of high-quality reservoirs in similar areas with complete outcrops. Full article

(This article belongs to the Special Issue Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources)

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12 pages, 9347 KiB

Open AccessArticle

The Strike-Slip Fault Effects on the Ediacaran Carbonate Tight Reservoirs in the Central Sichuan Basin, China

by Bing He, Yicheng Liu, Chen Qiu, Yun Liu, Chen Su, Qingsong Tang, Weizhen Tian and Guanghui Wu

Energies 2023, 16(10), 4041; https://doi.org/10.3390/en16104041 - 11 May 2023

Viewed by 1119

Abstract

The largest Precambrian gas field in China has been found in the central Sichuan Basin. It is assumed as a mound-shoal microfacies-controlled dolomite reservoir. Recently, a large strike-slip fault system has been identified in the gas field that needs further study of its effect on the Ediacaran reservoirs for highly efficient exploitation of the gas field. For this contribution, we study the matrix reservoir and fractured reservoir along the strike-slip fault damage zones by the cores, FMI (Formation MicroScanner Image) and logging interpretation data, seismic description and production data. It has shown that the matrix reservoir is tight (porosity less than 3%, permeability less than 0.5 mD) that cannot support economical production by conventional exploitation technology in the deep subsurface. On the other hand, the porosity and permeability of the Ediacaran fractured reservoirs could be increased more than one time and 1–3 orders of magnitude. Except for a few localized fracture zones, the fracture elements and fractured reservoirs show a paw-law distribution with the distance to the fault core. Furthermore, the fault effect is more favorable for the increase in the porosity and permeability of the matrix reservoir in the intraplatform than in the platform margin. The overlapping of mound-shoal microfacies, fracturing and karstification could result in large-scale “sweet spots” of the fractured reservoirs in the fault damage zone. The “sweet spot” of fractured reservoir in the fault damage zone is a new favorable exploitation target in the deep central Sichuan Basin. Full article

(This article belongs to the Special Issue Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources)

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16 pages, 8382 KiB

Open AccessArticle

Research on Microscopic Pore Structure Characteristics and Influencing Factors of Shale Reservoirs: A Case Study of the Second Member of the Permian Lucaogou Formation in Malang Sag, Santanghu Basin

by Xuejuan Zhang, Dandan Wang, Lei Zhang, Yabing Xing, Yi Zhang, Weiming Wang, Yinglin Liu and Hongping Mao

Energies 2023, 16(5), 2453; https://doi.org/10.3390/en16052453 - 4 Mar 2023

Cited by 4 | Viewed by 1344

Abstract

For the second member of the Permian Lucaogou Formation in Malang Sag, Santanghu Basin, we used field emission scanning electron microscopy (SEM), cryogenic nitrogen gas adsorption, and the micro/nano CT method, combined with the fractal theory, to depict the dense reservoir space types of the reservoir and the microcosmic pore structure characteristics, perform the quantitative evaluation of aperture size, pore shape, and connectivity, and to analyze the mineral composition of the micropore structure of the reservoir. The results show that the area is dominated by sandy/argillaceous dolomite, and the reservoir space types mainly develop dissolved intergranular pores and intergranular pores, a few microfractures, and parallel plate and slit nanoscale pores. There is a positive correlation between pore volume and specific surface area, with micropore volume accounting for 14.95%, mesopore volume at 82.47%, and macropore volume at 2.58%. The mesoporous volume provides the main pore storage space. The combined specific surface area of micropores and mesoporous pores accounts for more than 99% of the total specific surface area, providing almost all the pore surface area, which is the main site for shale oil and gas adsorption. The fractal dimension D value of the samples is between 2.39 and 2.49, and the pore distribution of shale is relatively uniform, mainly developing mesoporous pores. The specific surface area and average radius are positively correlated with the content of dolomite in mineral components. The results of the CT experiment also confirm that the pore throat of samples with high dolomite content is mostly a coarse tubular and banded distribution in three-dimensional space, with good connectivity. Full article

(This article belongs to the Special Issue Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources)

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22 pages, 24721 KiB

Open AccessArticle

Reactive Transport Modeling of CO₂-Brine–Rock Interaction on Long-Term CO₂ Sequestration in Shihezi Formation

by Zhuo Li, Yanfang Lv, Bin Liu and Xiaofei Fu

Energies 2023, 16(2), 670; https://doi.org/10.3390/en16020670 - 6 Jan 2023

Cited by 3 | Viewed by 1702

Abstract

Carbon Capture and Storage (CCS) is attracting increasing scientific attention. Although experiments can explore the chemical process of CO₂ sequestration, they are limited in time. CO₂ geological storage will last hundreds and thousands of years, even much longer, so the numerical simulation method is used to conduct kinetic batch modeling and reactive transport modeling. The geochemical simulation tool—TOUGHREACT—is used to imitate CO₂-brine–rock interactions at the Shihezi Formation in the Ordos basin. The mechanisms of CO₂-brine–rock interaction and their effects on the reservoir are discussed, especially the change in structure and properties. K-feldspar and albite will dissolve as the main primary minerals. However, calcite and quartz will dissolve first and precipitate last. In addition, siderite and ankerite also appear as precipitation minerals. Mineral dissolution and precipitation will alter the formation of petrophysical parameters, such as porosity and permeability, which play significant roles in the geological storage environments. Although the CO₂-brine–rock interaction rate may be small, it is an ideal way of geological storage. Regardless of what minerals dissolve and precipitate, they will improve the dissolution of CO₂. The interaction between rock and brine with dissolved CO₂ can promote the amount of mineralization of CO₂, called mineral trapping, which has a positive effect on the long-term feasibility of CO₂ storage. Full article

(This article belongs to the Special Issue Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources)

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10 pages, 4823 KiB

Open AccessArticle

Prediction Method and Application of Hydrocarbon Fluid Migration through Faulted Cap Rocks

by Bowei Zhang and Guang Fu

Energies 2023, 16(1), 290; https://doi.org/10.3390/en16010290 - 27 Dec 2022

Viewed by 1031

Abstract

Hydrocarbon fluid migration through faulted cap rocks was determined by comparing the maximum connected thickness of cap rocks required for hydrocarbon fluid migration and the actual values, since cap rocks are important in the study of hydrocarbon fluid distribution in petroliferous basins based on its migration mechanism(s). The maximum connected thickness required was identified by comparing the cap rocks, fault displacement, and oil/gas distribution. The hydrocarbon fluid at the Putaohua reservoir migrated to the overlying Saertu and Heidimiao reservoirs in the Bayan Chagan Area, northern Songliao Basin. This was predicted to demonstrate the validity of the method. The results show that the adjusted Putaohua oil reservoir was distributed near the Talahai fault and Bayanchagan fault, rather than the Gulong sag in the southwest of the study area, where oil migrated vertically through the Sapu cap rocks to the overlying Saertu reservoir. Thick mudstone cap rocks in the second member of the Nenjiang Formation made it difficult for hydrocarbon fluid to migrate to the Heidimiao reservoir. This agrees well with hydrocarbon fluid distribution at the Putaohua, Saertu, and Heidimiao reservoirs in the Bayan Chagan Area, indicating that this method is feasible for predicting hydrocarbon fluid migration through faulted cap rocks. Full article

(This article belongs to the Special Issue Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources)

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17 pages, 6461 KiB

Open AccessFeature PaperArticle

Numerical Simulation of CO₂ Migration and Geochemical Reactions in Shihezi Formation Caprock, China

by Zhuo Li, Yanfang Lv and Bin Liu

Energies 2023, 16(1), 92; https://doi.org/10.3390/en16010092 - 21 Dec 2022

Cited by 1 | Viewed by 1205

Abstract

CO₂ geological storage, which is an effective way to reduce CO₂ emissions, is of great significance to mitigate the current greenhouse effect. In long-term CO₂ storage, although the chemical reaction rate of CO₂–brine–rock is slow, it can significantly change the mineral composition of rock and the structure and properties of pores and joints, and then change the transport process and distribution state of CO₂ in porous media. Therefore, a simplified 2D geological model is established based on the geological data of the Shihezi Formation in the Ordos Basin, China. The mechanism of the CO₂–brine–rock reaction and its effect on mineral transformation and pore permeability are studied. In the early stage of CO₂ geological sequestration, the rate of CO₂ intrusion into the caprock is fast, the CO₂–brine–rock reaction in the early stage is mainly a dissolution reaction, and the porosity and permeability of the caprock show an increasing trend. During the period from 100 to 1000 years of CO₂ sequestration, the vertical distance of CO₂ intrusion into the caprock does not change much. During this period, the type of CO₂–brine–rock reaction is mainly a precipitation reaction, which reduces the porosity and permeability of the caprock and increases the sealing ability of the caprock to a certain extent. Our results can not only provide theoretical support for the site selection and risk assessment of CO₂ geological sequestration, but also provide a theoretical basis and practical guidance for large-scale commercial storage in the future. Full article

(This article belongs to the Special Issue Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources)

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27 pages, 9514 KiB

Open AccessArticle

Sedimentary Characteristics and Their Controlling Factors of Lower Cretaceous Fan Deltas in Saidong Sub-Sag of Saihantala Sag, Erlian Basin, Northeastern China

by Bo Yan, Hongqi Yuan, Xuanlong Shan, Tianqi Zhou and Shengfei Liu

Energies 2022, 15(22), 8373; https://doi.org/10.3390/en15228373 - 9 Nov 2022

Cited by 3 | Viewed by 1800

Abstract

Fan deltas of the Lower Cretaceous area in Saihantala sag, Erlian Basin have been identified as major petroleum exploration opportunities. The sedimentary evolution is, however, still debatable, which hinders insights into its controlling factors. This research employed new core observations, thin section observations, and grain size analyses of 28 wells in the Saidong sub-sag, together with numerous borehole and seismic data points, to explore lithofacies types, subfacies, and microfacies characteristics, thus leading to a further investigation of the sedimentary facies evolution of the sag and its controlling factors. The findings showed there are 3 categories, 12 sub-categories, and 20 fine lithofacies types in the Saidong sub-sag. Additionally, various sand-conglomerate lithofacies were characterized by lower composition and texture maturity. With dentate-shaped, box-bell-shaped, and other morphological well-logging responses, fan deltas were mostly developed in the A’ershan Formation and the Tengge’er Formation, which could be subdivided into three subfacies and eight microfacies. Given the sedimentary features and lithofacies characteristics of each microfacies, it can be determined that three main stages occurred in formations from the A’ershan to the Tengge’er: the water transgression, the water oscillation, and the water regression. Moreover, fan delta deposits were regulated primarily by semi-arid hygrothermal and semi-arid paleoclimate and paleotectonic factors. Full article

(This article belongs to the Special Issue Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources)

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11 pages, 2775 KiB

Open AccessArticle

Fault Evolution and Its Effect on the Sealing Ability of Mudstone Cap Rocks

by Mugui Liang, Guang Fu, Qiaoqiao Li, Heyao Guo and Bowei Zhang

Energies 2022, 15(20), 7676; https://doi.org/10.3390/en15207676 - 18 Oct 2022

Cited by 3 | Viewed by 1273

Abstract

To study the spatial distribution and scale of oil and gas near faults in petroliferous basins, a prediction model is established for the degree of damage that faults in different stages of evolution exert on the sealing ability of mudstone cap rocks by calculating the stages and degree of fault damage to the sealing ability of mudstone cap rocks. This model is applied to the Nanpu 5th Structure and the results show that at survey lines L2 and L8, the F1 Fault destroyed the sealing capacity of mudstone cap rock of the 2nd member of Dongying Formation (E₃d₂). The undamaged cap rock stage, when the degree of damage was zero, persisted from 23.8 to 16.0 Ma at survey line L2 and from 23.8 to 13.6 Ma at survey line L8. Complete destruction, i.e., where the degree of damage was 100%, at survey lines L2 and L8 occurred from 16.0 to 13.3 Ma and from 13.6 to 13.3 Ma, respectively. The partial destruction stage began 13.3 Ma ago and persists today; the degrees of damage at survey lines L2 and L8 were 89.96% and 82.58%, respectively. This was not conducive to oil and gas accumulation in the reservoir under the mudstone cap rock of E₃d₂. These results agreed with the current findings of small amounts of oil and gas under the mudstone cap rock of E₃d₂ at survey line L8 and no oil and gas at survey line L2. This indicates that the model is feasible for predicting the degree of damage to the sealing ability of the mudstone cap rocks by faults at different stages in their evolution. Full article

(This article belongs to the Special Issue Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources)

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12 pages, 6961 KiB

Open AccessArticle

Study on Morphological Identification of Tight Oil Reservoir Residual Oil after Water Flooding in Secondary Oil Layers Based on Convolution Neural Network

by Ling Zhao, Xianda Sun, Fang Liu, Pengzhen Wang and Lijuan Chang

Energies 2022, 15(15), 5367; https://doi.org/10.3390/en15155367 - 25 Jul 2022

Cited by 2 | Viewed by 1315

Abstract

In this paper, a microscopic oil displacement visualization experiment based on the glass etching model to simulate the tight oil reservoir of underground rocks is carried out. At present, water flooding technology is widely used in the development of oil and gas fields, and the remaining oil content is still very high after water flooding. It is the key to improving oil recovery to identify and study the remaining oil form distribution after water flooding. The experiment result shows there are five types of residual oil after water flooding: columnar residual oil, membranous residual oil, oil droplet residual oil, blind terminal residual oil and cluster residual oil. A convolution neural network is suitable for complex image characteristics with good robustness. In recent years, it has made a breakthrough in a set of small and efficient neural networks with SqueezeNet, Google Inception and the flattened network method put forward. In order to solve the problems of low automation, low efficiency and high error rate in the traditional remaining oil form recognition algorithm after water flooding in tight oil reservoirs, an image recognition algorithm based on the MobileNets convolutional neural network model was proposed in this paper to achieve accurate recognition of the remaining oil form. Based on traditional image processing methods which, respectively, extracted the whole picture of the different types of remaining oil in the image block, it uses the MobileNets network structure to classify different types of image block and realizes the layered depth convolution neural network system. The experiment result shows that the model can accurately identify the remaining oil forms, and the overall recognition accuracy is up to 83.8% after the convergence of the network model, which infinitely identifies the remaining oil forms in the morphological library, proving the strong generalization and robustness of the model. Full article

(This article belongs to the Special Issue Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources)

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Review

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19 pages, 4435 KiB

Open AccessReview

Research Status, Existing Problems, and the Prospect of New Methods of Determining the Lower Limit of the Physical Properties of Tight Sandstone Reservoirs

by Weiming Wang, Qingguo Liu, Yingnan Liu, Rigong Zhang, Tian Cheng, Youguo Yan, Qianze Hu and Tingting Li

Energies 2023, 16(15), 5664; https://doi.org/10.3390/en16155664 - 27 Jul 2023

Viewed by 874

Abstract

At present, many methods are used to determine the lower limits of physical properties (PPLLs) of tight sandstone reservoirs, such as empirical statistics, oil occurrence, and logging parameter crossplots, but the accuracy with which these methods obtain the lower limit of physical properties depends entirely on the number of test production data, and they are not suitable for tight sandstone reservoirs with a low degree of exploration and a lack of prediction. Compared to these mature methods, it can be concluded that the water-film-thickness-based method, which integrates factors such as formation temperature, formation pressure, mineral wettability, and formation water salinity, can characterize PPLLs using the minimum pore throat radius for hydrocarbon migration, which has a better theoretical basis and technical advantages. However, the water-film thickness is not a fixed value and cannot be directly measured in the laboratory. The molecular simulation method, known as a computational microscope, has become an effective means of investigating nano effects. By accurately investigating the interactions between rock minerals and the formation of water on atomic and molecular scales based on increasingly improved studies of the molecular force field, this method can overcome the deficiencies of the laboratory study of water films and precisely characterize the water films’ thickness. The intersection of molecular simulation and geology can bring about new methods and new research ideas for determining the lower limit of the physical properties of tight sandstone reservoirs and has broad application prospects. Full article

(This article belongs to the Special Issue Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources)

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29 pages, 7171 KiB

Open AccessReview

Research Progress and Prospect of Carbon Dioxide Utilization and Storage Based on Unconventional Oil and Gas Development

by Lei Li, Xue Zhang, Jiahui Liu, Qiuheng Xie, Xiaomei Zhou, Jianyang Zheng and Yuliang Su

Energies 2022, 15(24), 9383; https://doi.org/10.3390/en15249383 - 11 Dec 2022

Cited by 4 | Viewed by 2192

Abstract

Energy security and the reduction of greenhouse gases such as carbon dioxide are two major crises facing the world today. Using carbon dioxide to develop unconventional oil and gas resources is a positive way to reduce greenhouse gas emissions, which can significantly alleviate global energy security issues. This study systematically introduces the prerequisites for CO₂ to extract crude oil and CO₂ to be safely and effectively stored. Under high temperature and high pressure, the rock properties of deep reservoirs are completely different from those of atmospheric conditions in the two-phase porous media environment of crude oil and high salinity formation water. The research progress on the phase behavior, mutual solubility, CO₂ storage potential and mechanism between supercritical CO₂ and crude oil, formation water and reservoir are reviewed in detail. In addition, CO₂ leakage will inevitably occur during long-term geological storage, the proper estimation and evaluation of the risk and establishment of corresponding sealing methods are the way forward for CO₂ geological storage. By systematically elaborating the nature, advantages and disadvantages of fluid–fluid, fluid–solid interaction and geological integrity destruction mechanism, the directions in which several key problems should be solved were pointed out. Full article

(This article belongs to the Special Issue Geological Characteristics, Evaluation Methods and Exploration Prospects of Tight Oil and Gas Resources)

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