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Energies
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Reservoir Characterization on Conventional and Unconventional Resources
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Reservoir Characterization on Conventional and Unconventional Resources

A special issue of Energies (ISSN 1996-1073). This special issue belongs to the section "H: Geo-Energy".

Deadline for manuscript submissions: closed (30 December 2022) | Viewed by 6534

Special Issue Editors

Dr. Ahmed E. Radwan

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Guest Editor
Kraków Institute of Geological Sciences, Jagiellonian University, Krakow, Poland
Interests: subsurface analysis, including petroleum geology, reservoir characterization, carbonate and siliciclastic sedimentology, diagenesis, paleo-environment interpretations, paleoclimatology, basin analysis and unconventional and conventional resources; applied geophysics areas, including formation evaluation, petrophysics, borehole geophysics and rock typing; petroleum geochemistry, including geochemical characterization, basin modeling, petroleum system analysis and isotope analysis; petroleum geomechanics, including pore pressure, wellbore stability, in situ stress orientation and magnitudes; anthropocene and climate change; petroleum and reservoir engineering, including reservoir geology and geophysics, reservoir damage, production optimization, water flooding, stimulations, fluid flow, enhanced recovery, drilling, fluids and casing design; machine learning application in the petroleum industry
Special Issues, Collections and Topics in MDPI journals
Dr. Jin Lai

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Guest Editor
Department of Geology, China University of Petroleum-Beijing, Beijing, China
Interests: diagenetic evolution of tight sandstones; well log analysis of diagenetic facies; pore structure characterization of tight sandstones; fracture analysis; diagenesis within the sequence stratigraphy context; well log analysis of carbonate reservoirs

Special Issue Information

Dear Colleagues,

Understanding reservoir characterization is the first step towards the better exploitation of energy resources. In recent decades, several studies have been focused on the reservoir characteristics of conventional resources. However, unconventional resources have gained more attention as alternative future energy solutions rather than depleted conventional resources. The energy industry is facing technical challenges in terms of drilling, exploration, development and production of conventional and unconventional resources. This Special Issue will attempt to cover the most pressing technical challenges for developing both conventional reservoirs (e.g., sandstone and carbonate reservoirs) and unconventional energy sources (e.g., shale gas, shale oil, tight gas sand, coalbed methane, geothermal and gas hydrates).

Topics of interest will include:

  • Sedimentological and diagenesis analysis;
  • Pore evolution and structure of reservoirs;
  • Geochemical characteristics;
  • Petroleum geomechanics;
  • Well logging application in resource assessment;
  • Machine learning application;
  • EOR and CO2 storage;
  • Subsurface modeling;
  • Case studies;
  • Reservoir engineering (e.g., formation damage, production optimization, water flooding, stimulations, fluid flow, enhanced recovery, drilling, fluids and casing design).

Dr. Ahmed E. Radwan
Dr. Jin Lai
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

  • pore evolution
  • reservoir characterization
  • conventional resources
  • unconventional resources
  • EOR
  • reservoir engineering
  • machine learning
  • petroleum geomechanics
  • geochemical characterization

Published Papers (4 papers)

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Research

13 pages, 3558 KiB  
Article
In Situ Stress Determination Based on Acoustic Image Logs and Borehole Measurements in the In-Adaoui and Bourarhat Hydrocarbon Fields, Eastern Algeria
by Rafik Baouche, Souvik Sen, Ahmed E. Radwan and Ahmed Abd El Aal
Energies 2023, 16(10), 4079; https://doi.org/10.3390/en16104079 - 13 May 2023
Cited by 3 | Viewed by 1363
Abstract
The study of in situ stress from image logs is a key factor for understanding regional stresses and the exploitation of hydrocarbon resources. This work presents a comprehensive geomechanical analysis of two eastern Algerian hydrocarbon fields to infer the magnitudes of principal stress [...] Read more.
The study of in situ stress from image logs is a key factor for understanding regional stresses and the exploitation of hydrocarbon resources. This work presents a comprehensive geomechanical analysis of two eastern Algerian hydrocarbon fields to infer the magnitudes of principal stress components and stress field orientation. Acoustic image logs and borehole measurements were used in this research to aid our understanding of regional stress and field development. The studied In-Adaoui and Bourarhat fields encompass a combined thickness of 3050 m of Paleozoic and Mesozoic stratigraphy, with the primary reservoir facies in the Ordovician interval. The Ordovician sandstone reservoir interval indicates an average Poisson’s ratio (v) of 0.3, 100–150 MPa UCS, and 27–52 GPa Young’s modulus (E). Direct formation pressure measurements indicate that the sandstone reservoir is in a hydrostatic pore pressure regime. Density-derived vertical stress had a 1.1 PSI/feet gradient. Minimum horizontal stress modeled from both Poisson’s ratio and an effective stress ratio-based approach yielded an average 0.82 PSI/feet gradient, as validated with the leak-off test data. Drilling-induced tensile fractures (DITF) and compressive failures, i.e., breakouts (BO), were identified from acoustic image logs. On the basis of the DITF criterion, the maximum horizontal stress gradient was found to be 1.57–1.71 PSI/feet, while the BO width-derived gradient was 1.27–1.37 PSI/feet. Relative stress magnitudes indicate a strike-slip stress regime. A mean SHMax orientation of N130°E (NW-SE) was interpreted from the wellbore failures, classified as B-quality stress indicators following the World Stress Map (WSM) ranking scheme. The inferred stress magnitude and orientation were in agreement with the regional trend of the western Mediterranean region and provide a basis for field development and hydraulic fracturing in the low-permeable reservoir. On the basis of the geomechanical assessments, drilling and reservoir development strategies are discussed, and optimization opportunities are identified. Full article
(This article belongs to the Special Issue Reservoir Characterization on Conventional and Unconventional Resources)
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14 pages, 8814 KiB  
Article
Geomechanical and Petrophysical Assessment of the Lower Turonian Tight Carbonates, Southeastern Constantine Basin, Algeria: Implications for Unconventional Reservoir Development and Fracture Reactivation Potential
by Rafik Baouche, Souvik Sen and Ahmed E. Radwan
Energies 2022, 15(21), 7901; https://doi.org/10.3390/en15217901 - 25 Oct 2022
Cited by 14 | Viewed by 1335
Abstract
In this study, we assessed the unconventional reservoir characteristics of the Lower Turonian carbonates from the southeastern Constantine Basin. We integrated petrography, petrophysical, and rock-mechanical assessments to infer formation properties and unconventional reservoir development strategies. The studied fossiliferous argillaceous limestones are rich in [...] Read more.
In this study, we assessed the unconventional reservoir characteristics of the Lower Turonian carbonates from the southeastern Constantine Basin. We integrated petrography, petrophysical, and rock-mechanical assessments to infer formation properties and unconventional reservoir development strategies. The studied fossiliferous argillaceous limestones are rich in planktonic foraminifera, deposited in a calm and low energy depositional condition, i.e., deep marine basinal environment. Routine core analysis exhibits very poor porosity (mostly < 5%) and permeability (<0.1 mD), implying the dominance of nano and microporosity. Micritization and calcite cementation are inferred as the major reservoir quality-destroying diagenetic factors. Based on the wireline log-based elastic properties, the upper part of the studied interval exhibits higher brittleness (BI > 0.48) and fracability (FI > 0.5) indices compared to the lower interval. Borehole breakouts indicate ~N-S SHmax orientation and a normal to strike-slip transitional stress state has been constrained based on a geomechanical assessment. We analyzed safe wellbore trajectory and minimum mud weight requirements to ensure stability in the deviated and horizontal wells required for field development. At the present stress state, none of the fracture orientations are critically stressed. We inferred the fracture reactivation potential during hydraulic stimulation required to bring the tight Turonian limestones into production. Additional pore pressure build-up required to reactivate optimally oriented natural fractures has also been inferred to ensure success of hydraulic fracturing. Full article
(This article belongs to the Special Issue Reservoir Characterization on Conventional and Unconventional Resources)
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22 pages, 5646 KiB  
Article
Drilling in Complex Pore Pressure Regimes: Analysis of Wellbore Stability Applying the Depth of Failure Approach
by Ahmed E. Radwan
Energies 2022, 15(21), 7872; https://doi.org/10.3390/en15217872 - 24 Oct 2022
Cited by 17 | Viewed by 1888
Abstract
Most old oil and gas fields worldwide are depleted, making drilling in these sedimentary zones extremely difficult, especially in complex pore pressure regimes when they are accompanied by over-pressure zones. Considering that typical wellbore stability studies provide a conservative mud density curve to [...] Read more.
Most old oil and gas fields worldwide are depleted, making drilling in these sedimentary zones extremely difficult, especially in complex pore pressure regimes when they are accompanied by over-pressure zones. Considering that typical wellbore stability studies provide a conservative mud density curve to prevent wellbore failure, dynamic geomechanical approaches are required to provide more flexible and manageable drilling in such complex cases in order to address anticipated drilling obstacles. This study aims to apply the more dynamic concept, known as “depth of damage” (DOD), in the El Morgan oil field, Gulf of Suez Basin, to deliver a more optional mud density window that helps in the safe drilling of different pore pressure regimes within the area, as well as the implications of applying this drilling strategy in the studied basin. In this paper, well logging and downhole measurements were used to develop a 1D geomechanical earth model and infer the in situ stresses in the studied boreholes, and the modified Lade failure criterion was used to conduct the wellbore stability analysis. The study revealed that the El Morgan sedimentary succession has a complex and varied pore pressure regime. Applying the DOD approach introduces multiple mud density scenarios that can lead to successful drilling and avoid unexpected incidents while drilling. The key benefit of the DOD approach is that it widens the safe mud density window to be less than the shear failure with an acceptable amount of failure. This study provides insights into unconventional techniques such as underbalanced drilling techniques that can be used under manageable conditions in mature basins. Furthermore, the DOD approach is compared to the conventional wellbore stability analysis or breakout depth approach, and the main differences, merits, and demerits of each were discussed in this study. Full article
(This article belongs to the Special Issue Reservoir Characterization on Conventional and Unconventional Resources)
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22 pages, 5752 KiB  
Article
Petroleum Resource Potential Assessment of Members 1 and 3 of the Paleogene Shahejie Formation, Qikou Sag: Insights from Hydrocarbon Generation and Expulsion Capabilities
by Zhuoya Wu and Xianzheng Zhao
Energies 2022, 15(19), 7078; https://doi.org/10.3390/en15197078 - 26 Sep 2022
Viewed by 1072
Abstract
The Shahejie Formation (Fm) in the Bohai Bay Basin is well-known for its substantial conventional resource potential and long-term history of exploration. Shale oil has been confirmed as a sustainable resource following breakthroughs in shale exploration in the first and third members of [...] Read more.
The Shahejie Formation (Fm) in the Bohai Bay Basin is well-known for its substantial conventional resource potential and long-term history of exploration. Shale oil has been confirmed as a sustainable resource following breakthroughs in shale exploration in the first and third members of the Paleogene Shahejie Fm (Mbr1 and Mbr3) in Qikou Sag, particularly Mbr3, which has a more desirable output. However, the limited distribution of exploration wells for shale oil around the southwest of Qikou Sag calls for a comprehensive evaluation of shale oil (or gas) potential in all of Qikou Sag. Here, we clarify the shale oil (or gas) resource potential and areas favorable for exploration in Mbr3 by using a hydrocarbon generation potential model (HGPM) based on the material balance method and the principle of hydrocarbon (HC) generation dynamics. Apart from the quantified characteristics of the oil generation process of Mbr3 source rocks, the source rocks of both Mbr1 and Mbr3 were compared to interpret the discrepancies in HC generation. The results show that Mbr3 source rocks have high-quality geological and geochemical features, a thickness of 1200 m, and adequate organic matter (1.66% TOC on average, dominated by kerogen II&III, and in the mature stage). The threshold of expulsion is Ro = 0.78%; correspondingly, HC generation potential (Qg), HC expulsion potential (Qe), and retention potential (Qr) are, at maximum, 605.89, 169.65, and 436.24 mg HC/g TOC. The intensity of HC generation (Ig), expulsion (Ie), retention (Ir), and effective retention (Ire) is focused on the main depression and the Qibei Sub-sag and can reach as high as 250 × 104, 65 × 104, 170 × 104, and 110 × 104 t/km2, respectively. The resource potential for the retention of shale was calculated to be 13.3 × 108 t (movable shale oil and gas 8.0 × 108 t), and conventional and tight oil or gas resources were calculated to be 4.7 × 108 t (equivalent oil resources). Favorable exploration targets are spread around the main depression and the Qibei Sub-sag. There are disparities in the thermal process and thermal generation, and expulsion features between Mbr1 and Mbr3 source rocks are derived from kerogen-type and non-isolated deposit environments. Thus, a quantitative, advanced evaluation and a comparison offer more precise exploration predictions of shale in this Fm and further boost the low-risk exploration process. Full article
(This article belongs to the Special Issue Reservoir Characterization on Conventional and Unconventional Resources)
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