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Energies
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New Insights into Reservoir 3D Modeling and Simulation
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New Insights into Reservoir 3D Modeling and Simulation

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

Deadline for manuscript submissions: closed (25 March 2024) | Viewed by 10140

Special Issue Editor

Dr. S.M. Talha Qadri

E-Mail Website1 Website2
Guest Editor
School of Land Use and Environmental Change, University of the Fraser Valley, King Road, Abbotsford, BC V2S 7M8, Canada
Interests: reservoir modeling; petroleum system analysis; reservoir characterization through 3D modeling; geosciences

Special Issue Information

Dear Colleagues, 

Preface:

The recent rise in the fuel demand from automobile and other linked industries have increased the hydrocarbon production from the established reservoirs worldwide. This increase in demand has also shown the immense dependency of society on the hydrocarbon industry. It has forced the hydrocarbon related scientists and policy makers towards more discoveries and re-evaluations of the already discovered petroleum systems. The advancement in reservoir Modeling and simulation techniques is a critical tool in achieving sustainability for our society.

This special issue focuses on the recent advances and state of art research contributions in the 3D reservoir Modeling and simulation including; reservoir characterization techniques, machine learning models, petroleum system models and applications.

Subject Coverage:

The relevant case studies, review and original papers are invited for this special issue. The submission should focus, but are not limited to, the following areas in context to 3D Reservoir Modeling and Simulation:

  • 3D Modeling in Petroleum Geosciences
  • Advances in Petrophysics
  • Seismic interpretation
  • Source to Reservoir characterization
  • Petroleum System Modeling
  • Machine Learning & Artficial Intelligence Approaches in Reservoir Evaluation
  • Conventional and Unconventional Reservoir Modeling

Dr. S.M. Talha Qadri
Guest Editor

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

  • Reservoir Modeling
  • Reservoir Characterization
  • Petroleum System Analysis/Modeling
  • Advances in Petrophysics
  • Machine Learning for Reservoir Modeling
  • Artificial Intelligence for Reservoir Modeling

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Published Papers (4 papers)

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Research

14 pages, 3082 KiB  
Article
Global Genetic Algorithm for Automating and Optimizing Petroleum Well Deployment in Complex Reservoirs
by Sonny Irawan, Dennis Delali Kwesi Wayo, Alfrendo Satyanaga and Jong Kim
Energies 2024, 17(9), 2151; https://doi.org/10.3390/en17092151 - 30 Apr 2024
Cited by 2 | Viewed by 1142
Abstract
Locating petroleum-productive wells using informed geological data, a conventional means, has proven to be tedious and undesirable by reservoir engineers. The former numerical simulator required a lengthy trial-and-error process to manipulate the variables and uncertainties that lie on the reservoir to determine the [...] Read more.
Locating petroleum-productive wells using informed geological data, a conventional means, has proven to be tedious and undesirable by reservoir engineers. The former numerical simulator required a lengthy trial-and-error process to manipulate the variables and uncertainties that lie on the reservoir to determine the best placement of the well. Hence, this paper examines the use of a global genetic algorithm (GA) to optimize the placement of wells in complex reservoirs, rather than relying on gradient-based (GB) methods. This is because GB approaches are influenced by the solution’s surface gradient and may only reach local optima, as opposed to global optima. Complex reservoirs have rough surfaces with high uncertainties, which hinders the traditional gradient-based method from converging to global optima. The explicit focus of this study was to examine the impact of various initial well placement distributions, the number of random solution sizes and the crossover rate on cumulative oil production, the optimization of the synthetic reservoir model created by CMG Builder, CMOST, and IMEX indicated that using a greater number of random solutions led to an increase in cumulative oil production. Despite the successful optimization, more generations are required to reach the optimal solution, while the application of GA on our synthetic model has proven efficient for well placement; however, different optimization algorithms such as the improved particle swarm (PSO) and grey wolf optimization (GWO) algorithms could be used to redefine well-placement optimization in CMG. Full article
(This article belongs to the Special Issue New Insights into Reservoir 3D Modeling and Simulation)
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14 pages, 5798 KiB  
Article
3D Modeling of Fracture-Cave Reservoir from a Strike-Slip Fault-Controlled Carbonate Oilfield in Northwestern China
by Rujun Wang, Jianping Yang, Lunjie Chang, Yintao Zhang, Chong Sun, Xiaoguo Wan, Guanghui Wu and Bingchen Bai
Energies 2022, 15(17), 6415; https://doi.org/10.3390/en15176415 - 2 Sep 2022
Cited by 14 | Viewed by 2146
Abstract
A giant strike-slip fault-controlled Fuman Oilfield has been found in the Ordovician fractured carbonates of the Tarim Basin. However, conventional seismic methods are hardly able to distinguish the fractured reservoir and its connectivity in the ultra-depth (>7000 m) carbonate fault zones. We propose [...] Read more.
A giant strike-slip fault-controlled Fuman Oilfield has been found in the Ordovician fractured carbonates of the Tarim Basin. However, conventional seismic methods are hardly able to distinguish the fractured reservoir and its connectivity in the ultra-depth (>7000 m) carbonate fault zones. We propose thin-likelihood and tensor-thickness process methods to describe the fracture network and large cave reservoir, respectively. Together with the two methods for 3D visualization of fracture-cave reservoirs, we had an application in the ultra-deep well deployment in Fuman Oilfield. The results show that the fracture network and cave reservoir can be 3D-imaged more clearly than conventional methods. The fracture network and cave reservoir show distinct segmentation by the fault assemblage in Fuman Oilfield. Furthermore, 3D modeling is favorable for the reservoir connectivity description along the carbonate fault zones. There are three distinct reservoir models: fault core-, fault damage zone- and overlap zone-controlling fractured reservoirs along the fault zones. This revealed variable fractured reservoirs that are related to fault maturity and segmentation. The method has been widely used in fracture-cave reservoir description and subsequent well optimization, suggesting a favorable method for economic oil exploitation in the ultra-depth reservoirs. This case study is not only useful for the complicated reservoir 3D description and modeling but also helpful for well employment to provide support for the target evaluation and optimization in ultra-depth fractured reservoirs. Full article
(This article belongs to the Special Issue New Insights into Reservoir 3D Modeling and Simulation)
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12 pages, 12115 KiB  
Article
Strike-Slip Fault Effects on Diversity of the Ediacaran Mound-Shoal Distribution in the Central Sichuan Intracratonic Basin, China
by Long Wen, Qi Ran, Weizhen Tian, Han Liang, Yuan Zhong, Yu Zou, Chen Su and Guanghui Wu
Energies 2022, 15(16), 5910; https://doi.org/10.3390/en15165910 - 15 Aug 2022
Cited by 13 | Viewed by 1905
Abstract
The largest Precambrian gasfield in China has been found from the Ediacaran (Sinian) carbonates in the central Sichuan Basin. The deep ancient reservoirs were generally attributed to the high-energy mound-shoal body in the carbonate platform. However, there is still little understanding on the [...] Read more.
The largest Precambrian gasfield in China has been found from the Ediacaran (Sinian) carbonates in the central Sichuan Basin. The deep ancient reservoirs were generally attributed to the high-energy mound-shoal body in the carbonate platform. However, there is still little understanding on the distribution of the mound-shoal bodies that hampers further gas exploitation from the deep subsurface. Based on the seismic data, a large strike-slip fault system was identified by new 3D seismic data in the central Sichuan Basin. Further, it was found that the strike-slip fault had some effects on the mound-shoal bodies of the Ediacaran Dengying Formation. First, the platform margin was divided by strike-slip faults into three distinct segments to show two weak-rimmed margins and one interbedded rimmed margin. Second, the platform margin could be offset or migrated with the strike-slip faults. Third, there is varied margin thickness across the strike-slip fault zone. In the inner platform, more carbonate mound-shoal bodies developed behind the weak-rimmed margin that was divided by the strike-slip fault zones. In addition, the mound-shoal bodies may be separated by faulted sag. Further, the mound-shoal bodies may have developed along the faulted higher position in one side of the strike-slip fault zone. These patterns of the mound-shoal bodies suggest that the strike-slip fault had an important role in the sedimentary microfacies’ diversity in the intracratonic carbonates. The low displacement of the strike-slip fault is chiefly responsible for a weaker controlling effect on the microfacies change in the intracratonic basin rather than other tectonic settings. Full article
(This article belongs to the Special Issue New Insights into Reservoir 3D Modeling and Simulation)
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16 pages, 5068 KiB  
Article
Murree Clay Problems and Water-Based Drilling Mud Optimization: A Case Study from the Kohat Basin in Northwestern Pakistan
by S. M. Talha Qadri, Waqas Ahmed, A. K. M. Eahsanul Haque, Ahmed E. Radwan, Mohammad Hail Hakimi and Ahmed K. Abdel Aal
Energies 2022, 15(9), 3424; https://doi.org/10.3390/en15093424 - 7 May 2022
Cited by 15 | Viewed by 3782
Abstract
Drilling fluids with subtle filtration and rheological characteristics are essential to optimize the functioning of oil and gas well drills. The Early Miocene Murree Formation in the Kohat Basin of Pakistan is generally referred to as the Murree Clays. When mixed with water-base [...] Read more.
Drilling fluids with subtle filtration and rheological characteristics are essential to optimize the functioning of oil and gas well drills. The Early Miocene Murree Formation in the Kohat Basin of Pakistan is generally referred to as the Murree Clays. When mixed with water-base drilling mud, ultra-fine particles of the Murree Formation tend to eradicate default fluid rheological properties and result in wellbore instabilities during drilling in that area. To obtain the optimized mud to deliver the drilling operation efficiently, we aimed to mitigate the impact of Murree clay on the drilling mud. We analyzed the drilling mud to observe the effects of the mud additive on clays on the basis of the samples from the Murree Clays. On the basis of the experimental tests, we observed that the rheological properties of mud significantly improved in the presence of KCl. KCl prevented the smectite group swelling inclinations and reduced rheological values to 25%, 33.3%, 48.6%, and 65.2%. The plastic viscosity increased as the concentration of clays increased; however, there was a noticeable reduction in the yield point values with the introduction of KCl. The laboratory results showed that Mud + 4% Clay + 1% KCl proved to be the best mitigation while preserving the rheological and performance characteristics of the mud. Tests enabled the scope to increase the inhibition efficiency and optimize customization. Depending on the clay present in the Murree formation, drilling fluid optimization is proposed to reduce mud-related drilling problems in this area. Full article
(This article belongs to the Special Issue New Insights into Reservoir 3D Modeling and Simulation)
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