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Applied Sciences
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Modeling and Numerical Simulations in Petroleum Engineering
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Modeling and Numerical Simulations in Petroleum Engineering

A special issue of Applied Sciences (ISSN 2076-3417). This special issue belongs to the section "Energy Science and Technology".

Deadline for manuscript submissions: closed (10 December 2022) | Viewed by 5903

Special Issue Editors

Dr. Jianchun Xu

E-Mail Website
Guest Editor
School of Petroleum Engineering, China University of Petroleum (East China), Qingdao 266580, China
Interests: reservoir numerical simulation; production optimization; history matching/inverse problem; unconventional oil/gas
Special Issues, Collections and Topics in MDPI journals
Prof. Dr. Zhiyuan Wang

E-Mail Website
Guest Editor
School of Petroleum Engineering, China University of Petroleum (East China), Qingdao 266580, China
Interests: hydrate formation and deposition; hydrate inhibition; phase transition; hydrate slurry rheology; natural gas hydrate recovering
Special Issues, Collections and Topics in MDPI journals
Dr. Jianjun Zhu

E-Mail Website
Guest Editor
School of Storage and Transportation Engineering, China University of Petroleum (Beijing), Beijing 102249, China
Interests: multiphase flow; artificial lift (electric submersible pump, plunger lift, gas lift, etc.); data mining and analysis
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

Modeling and numerical simulation are wildly used in petroleum engineering for oil and gas exploration and production. The application fields include drilling and completions, production and facilities, oilfield chemistry, enhanced oil recovery, reservoir evaluation and engineering, data analytics, multiphase flow in porous media, multi-phase flow in wellbore, flow assurance and security, CO2 Sequestration in geological formations/sub-surface, development of unconventional resources such as tight oil, tight gas, coal bed methane, and gas hydrate. The Special Issue “Modeling and Numerical Simulations in Petroleum Engineering” will address the most recent advances in modeling methods and simulation techniques in oil and gas sectors. Submissions should discuss the use of modelling and numerical simulations in petroleum industry.

Potential topics include but are not limited to the following:

  • drilling and completions simulation
  • multi-phase wellbore flow simulation
  • multiphase, multicomponent flow in porous media
  • modelling and simulation of hydraulic fracture
  • flow simulation inside artificial lift systems
  • flow assurance analysis and modeling
  • numerical simulation of  unconventional oil and gas reservoirs

Dr. Jianchun Xu
Dr. Jianjun Zhu
Dr. Zhiyuan Wang
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. Applied Sciences 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 2400 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.

Published Papers (4 papers)

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Research

17 pages, 1588 KiB  
Article
Modeling the Submergence Depth of Oil Well States and Its Applications
by Tianshi Liu, Xue Tian, Liwen Liu, Xiaoyu Gu, Yun Zhao, Liumei Zhang and Xinai Song
Appl. Sci. 2022, 12(23), 12373; https://0-doi-org.brum.beds.ac.uk/10.3390/app122312373 - 02 Dec 2022
Viewed by 1116
Abstract
Obtaining the liquid storage state of oil wells in real time is very important for oilfield production. In this paper, under the premise of fully considering the transformation factors of full-pumping and nonfull-pumping states of oil wells, submergence depth models suitable for full- [...] Read more.
Obtaining the liquid storage state of oil wells in real time is very important for oilfield production. In this paper, under the premise of fully considering the transformation factors of full-pumping and nonfull-pumping states of oil wells, submergence depth models suitable for full- and nonfull-pumping wells are constructed. To reduce the application complexity of the models, parameter-reduction processing is performed to enhance the usability of the models. By analyzing the change trend of the submergence depth during the rising, maintaining, and falling of the oil well in the full-pumping state and nonfull-pumping state models, the judgment criteria for the transition of the oil well state are provided. On this basis, the application methods of nonlinear interpolation and least squares curve-fitting numerical solutions of submergence depth models are studied, and the unique existence of the solution of the corresponding one-variable nonlinear characteristic equation in the (0, 1) open interval is proven. Finally, the error estimation of the numerical solution is carried out, the calculation formula of the number of iterations for the numerical solution of the dichotomy is provided, and the error of the relevant numerical solution is verified. Full article
(This article belongs to the Special Issue Modeling and Numerical Simulations in Petroleum Engineering)
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12 pages, 4070 KiB  
Article
Heat Transfer Performance of a Downhole Electric Tubular Resistive Heater
by Yu Chen, Hao Zeng, Jianli Wang, Haoran Chen and Jianjun Zhu
Appl. Sci. 2022, 12(19), 9508; https://0-doi-org.brum.beds.ac.uk/10.3390/app12199508 - 22 Sep 2022
Cited by 1 | Viewed by 1306
Abstract
A downhole electric tubular resistive heater is proposed for the oil-shale in situ resorting. After flowing through a set of heating tubes, the outlet temperature and the flow rate of the injected gas can be conveniently adjusted to match the requirement of the [...] Read more.
A downhole electric tubular resistive heater is proposed for the oil-shale in situ resorting. After flowing through a set of heating tubes, the outlet temperature and the flow rate of the injected gas can be conveniently adjusted to match the requirement of the pyrolysis temperature of the oil shale. The calculation demonstrates the effects of the inner diameter, the length of the heating tube, and the inlet flow rate on the heat transfer performance of the electric heater. It was found that, compared with the armored electric heaters, even with a small inject flow rate of 5 Nm3/min, the convective heat transfer coefficient of the inner flow exceeds 300 W/m2 K, resulting in a much smaller thermal resistance. The outlet temperature of the heating gas can conveniently reach up to 900 °C with the absence of the complex structure of enhanced fins. Though the pressure loss is relatively larger under a high flow rate, the comprehensive index is still 40% higher, indicating that the present tubular electric heater is a promising candidate to deal with complex downhole conditions. Full article
(This article belongs to the Special Issue Modeling and Numerical Simulations in Petroleum Engineering)
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19 pages, 5740 KiB  
Article
Numerical Simulation of the Enrichment of Chemotactic Bacteria in Oil-Water Two-Phase Transfer Fields of Heterogeneous Porous Media
by Xiaopu Wang, Lianjie Hou, Tianhao He, Zhenhan Diao, Chuanjin Yao, Tao Long and Ling Fan
Appl. Sci. 2022, 12(10), 5215; https://0-doi-org.brum.beds.ac.uk/10.3390/app12105215 - 21 May 2022
Viewed by 1310
Abstract
Oil pollution in soil-groundwater systems is difficult to remove, and a large amount of residual oil is trapped in the low permeable layer of the heterogeneous aquifer. Aromatic hydrocarbons in oil have high toxicity and low solubility in water, which are harmful to [...] Read more.
Oil pollution in soil-groundwater systems is difficult to remove, and a large amount of residual oil is trapped in the low permeable layer of the heterogeneous aquifer. Aromatic hydrocarbons in oil have high toxicity and low solubility in water, which are harmful to the ecological environment. Chemotactic degrading bacteria can perceive the concentration gradient of non-aqueous phase liquid (NAPL) pollutants in the groundwater environment, and enrich and proliferate around the pollutants, thus achieving a more efficient and thorough remediation effect. However, the existing theoretical models are relatively simple. The physical fields of oil–water two-phase flow and oil-phase solute convection and diffusion in water are not coupled, which further restricts the accuracy of studies on bacterial chemotaxis to NAPL. In this study, geometric models based on the actual microfluidic experimental study were constructed. Based on the phase field model, diffusion convection equation and chemotaxis velocity equation, the effects of heterogeneity of porous media, wall wettability and groundwater flow rate on the residual oil and the concentration distribution of chemotaxis bacteria were studied. Under all of the simulation conditions, the residual oil in the high permeable area was significantly lower than that in the low permeable area, and the wall hydrophilicity enhanced the water flooding effect. Chemotactic bacteria could react to the concentration gradient of pollutants dissolved into water in the oil phase, and enrich near the oil–water interface with high concentration of NAPL, and the density of chemotactic bacteria at the oil–water interface can be up to 1.8–2 times higher than that in the water phase at flow rates from 1.13 to 6.78 m/d. Full article
(This article belongs to the Special Issue Modeling and Numerical Simulations in Petroleum Engineering)
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16 pages, 3955 KiB  
Article
Numerical Study on Transient Annular Pressure Caused by Hydration Heat during Well Cementing
by Xuerui Wang, Xueyu Pang, Ming Xian, Baojiang Sun, Zhiyuan Wang, Yong Ren, Yuqi Feng and Zhen Zhang
Appl. Sci. 2022, 12(7), 3556; https://0-doi-org.brum.beds.ac.uk/10.3390/app12073556 - 31 Mar 2022
Cited by 1 | Viewed by 1155
Abstract
Annular pressure has been recognized as one of the most challenging problems in the petroleum industry, posing a series of threats to wellbore integrity. Annular pressure caused by thermal expansion during the cement hydration process is rarely studied by researchers. In light of [...] Read more.
Annular pressure has been recognized as one of the most challenging problems in the petroleum industry, posing a series of threats to wellbore integrity. Annular pressure caused by thermal expansion during the cement hydration process is rarely studied by researchers. In light of the hydration heat generation process, a kinetics model for cement hydration under different curing temperatures is demonstrated in this paper. Considering interactions between temperature and cement hydration, a transient temperature prediction model during well cementing is built. On the basis of these assumptions, the prediction model of annular pressure is established, considering the change in cement temperature and the change in annulus volume. Using the models illustrated in this paper, a series of numerical simulations are performed. The changing roles of transient cement hydration degree and temperature in wellbores are analyzed thoroughly. The annular pressure during well cementing shows a rapid increase and then a decrease, which is similar to that of the temperature. In addition, a sensitive analysis of annular pressure is conducted. The analysis shows that the annular pressure increases with the geothermal gradient, the cement hydration heat, and the wellbore diameter. Suggestions and conclusions can provide safety guidance for the management of annular pressure during well cementing. Full article
(This article belongs to the Special Issue Modeling and Numerical Simulations in Petroleum Engineering)
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