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Energies
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Modeling and Production of Oil-Gas Reservoirs
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Modeling and Production of Oil-Gas Reservoirs

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

Deadline for manuscript submissions: closed (31 March 2023) | Viewed by 3590

Special Issue Editors

Prof. Dr. Jinjie Wang

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Guest Editor
Key Laboratory of Tectonics and Petroleum Resources (China University of Geosciences), Ministry of Education, Wuhan 430074, China
Interests: Enhanced oil and gas recovery; carbon capture utilization and storage; adsorption/desorption in shale; hydrate evaluation; reservoir simulation
Special Issues, Collections and Topics in MDPI journals
Dr. Kai Zhang

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Guest Editor
Department of Chemical and Petroleum Engineering, University of Calgary, Calgary, Canada
Interests: Reservoir modeling; CO2 enhanced oil recovery; carbon capture and storage
Dr. Martin Ma

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Guest Editor
Computational Earth Science, Los Alamos National Laboratory, Los Alamos, NM, USA
Interests: reservoir simulation; production optmization; machine learning; CO2 storage
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

The production of oil and gas reservoirs is the process of extracting hydrocarbons trapped underground. The production site can be onshore or offshore, while subsurface hydrocarbons can be found in sandstone, carbonate, shale reservoir, coalbed seam or gas hydrate, etc. The last few decades have seen significant technological advancements in the fields of oil and gas production. Although conventional oil and gas reservoirs are easily accessible, there are still significant challenges in the production of the oil and gas fields, particularly concerning how to properly reduce uncertainties in reservoir and fluid properties, how to effectively use operation histories, how to improve ultimate recovery and how to improve simulation efficiency, etc. To guide oil and gas production, updated knowledge and new understandings of oil and gas reservoir modelling are urgently needed. 

This Special Issue focuses on the modelling and production of oil and gas reservoirs. We aim to encompass original research and review articles highlighting the recent advances in new modelling techniques, the latest understanding of the production mechanisms, advanced algorithms for modelling, innovative methods of experiments, field pilots, etc. related to oil and gas production. Additionally, this Special Issue welcomes contributions that support and advance the UN's sustainable development goals, such as carbon capture and storage, renewable energy modelling, and net-zero emissions.

We invite researchers in the aforementioned fields to contribute with submissions.

Prof. Dr. Jinjie Wang
Dr. Kai Zhang
Dr. Zhiwei Ma
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

  • enhanced oil recovery for high water cut reservoirs
  • oil and gas production evaluation
  • reservoir modelling
  • experimental advances in unconventional reservoirs
  • simulation of fluid flow in shale and CBM rocks
  • estimation and evaluation of fracture networks
  • new advances in natural gas hydrate development
  • heavy oil/coal in-situ gasification
  • field development optimization
  • recent advances and applications of machine learning in production of oil and gas reservoirs
  • carbon capture, utilization and storage

Published Papers (2 papers)

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Research

22 pages, 31446 KiB  
Article
Influence of Sublacustrine Fan Depositional Model on Distribution and Morphology of Reservoirs: A Case Study in Eastern Slope of Liaoxi Uplift, Bohai Bay Basin, East China
by Hao Wang, Shu Jiang, Yuying Zhang, Xin Wang, Enhao Liu and Xiaobin Dong
Energies 2023, 16(2), 851; https://doi.org/10.3390/en16020851 - 11 Jan 2023
Cited by 1 | Viewed by 1335
Abstract
The study on morphology and distribution of sublacustrine fan are necessary for the exploration of oil and gas, which could help to effectively predict the reservoirs of sublacustrine fans. In this paper, the distribution and geomorphology of sublacustrine fans of Dongying Formation in [...] Read more.
The study on morphology and distribution of sublacustrine fan are necessary for the exploration of oil and gas, which could help to effectively predict the reservoirs of sublacustrine fans. In this paper, the distribution and geomorphology of sublacustrine fans of Dongying Formation in Liaoxi uplift (Bohai Bay Basin, East China) and their controlling factors (including shape and formations) have been analyzed in detail based on seismic, core, and logging data. The main conclusions achieved in this study are: (1) During the sequence of the third member of Dongying Formation (SQd3), two types of sublacustrine fan, including channelized fan (in channel shape) and non-channelized fan (in tongue shape and lobe shape), developed on the eastern slope of Liaoxi uplift, which inherited the characteristics of sediments structural maturity in braided river delta front (good sandstone sorting and high structural maturity); (2) Steep slope was favorable for forming tongue shape sublacustrine fans with large ratio of length and width, while gentle slope tended to deposit lobe shape fans; high mud content tended to form stable channels with strong erosion on the slope end, while high sand content tended to form continuous lobes with lobe shape; (3) In the basin with uplift, the beneficial combination among provenance, relative lake level change and paleomorphology, determines the development and distribution of sublacustrine fan, and the sublacustrine fan deposits are mainly concentrated in the TST. The Yanshan fold belt in the west provided sufficient sediments to the Liaodong Bay during LST for the development of a sublacustrine fan in the east slope of Liaoxi uplift since the Liaoxi uplift sunk into the water, with the result that the deposition of braided river delta front can overlap the uplift. The incised canyons in the Liaoxi uplift provided the channels for sediments entering into the eastern slope, and the main sedimentary location of lacustrine fans was between two stages of faults. This study could provide a theoretical basis for researching the characteristics and distribution of other sublacustrine fans in similar basin backgrounds. Full article
(This article belongs to the Special Issue Modeling and Production of Oil-Gas Reservoirs)
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12 pages, 6503 KiB  
Article
Factoring Permeability Anisotropy in Complex Carbonate Reservoirs in Selecting an Optimum Field Development Strategy
by Sergey Krivoshchekov, Alexander Kochnev, Nikita Kozyrev and Evgeny Ozhgibesov
Energies 2022, 15(23), 8866; https://doi.org/10.3390/en15238866 - 24 Nov 2022
Cited by 4 | Viewed by 1684
Abstract
Current methods of oil and gas field development design rely on reservoir simulation modeling. A reservoir simulation model is a tool to reproduce field development processes and forecast production data. Reservoir permeability is one of the basic properties that determines fluid flow. From [...] Read more.
Current methods of oil and gas field development design rely on reservoir simulation modeling. A reservoir simulation model is a tool to reproduce field development processes and forecast production data. Reservoir permeability is one of the basic properties that determines fluid flow. From existing approaches, the porosity and permeability values should be consistent with petrophysical correlations obtained from core sample tests in the course of development of an absolute permeability cube in the reservoir simulation model. For carbonate reservoirs with complex pore space structure and fractures, the petrophysical correlations are often unstable. To factor in the fluid flow in a fractured rock system, dual-medium models are developed, allowing for matrix and fracture components. Yet in this case, the degree of uncertainty only increases with the introduction of a new parameter: a cross-flow index of fluid migration from matrix to fracture, which is only determined indirectly by results of fluid flow studies conducted in the initial development period, and therefore most often is adaptive. Clearly, for well-studied fields there is an extensive data pool drawn on research findings: core studies, well logging, well flow testing, flowmetry, special well-logging methods (FMI, Sonic Scanner, etc.); the dual-medium model development for such reservoirs is fairly well-founded and supported by actual studies. However, at the start of the field development, the data are incomplete, which renders qualitative dual-medium modeling impossible. This paper proposes an approach to factor in the target’s permeability anisotropy at an early development stage through the integration of well, core and 3D seismic surveys. The reservoir was classified into pore space types, to which different petrophysical correlations were assigned to develop a permeability array, and relative phase permeabilities were studied. The fluid flow model was history-matched with allowance for permeability anisotropy and rock types. Comparative calculations were conducted on the resulting model to select the optimum development strategy for the target. Full article
(This article belongs to the Special Issue Modeling and Production of Oil-Gas Reservoirs)
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