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Petroleum and Natural Gas Engineering: 2nd Edition
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Petroleum and Natural Gas Engineering: 2nd Edition

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

Deadline for manuscript submissions: 31 October 2026 | Viewed by 4086

Special Issue Editors

Dr. Jiaxue Li

E-Mail Website
Guest Editor
Engineering Institute, China University of Petroleum (Beijing), Beijing 102249, China
Interests: oil and gas engineering oilfield surface engineering chemistry; natural gas transportation; harmless treatment technology for oil and gas field waste; drilling fluid and completion fluid
Special Issues, Collections and Topics in MDPI journals
Dr. Pengfei Zhao

E-Mail Website
Guest Editor
School of Geoscience and Technology, Southwest Petroleum University, Chengdu 610500, China
Interests: petroleum engineering; reservoir physics; rock mechanics
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

This Special Issue aims to highlight recent advancements and innovations in the field of petroleum and natural gas engineering, with a particular focus on hydraulic fracturing and enhanced oil recovery (EOR) techniques. These methods are crucial for optimizing extraction processes and improving overall production efficiency. We also seek to address the latest developments in drilling technologies, which play a supporting role in the exploration and extraction of petroleum and natural gas resources.

Topics of interest include the following:

  • Innovations in hydraulic fracturing fluids and proppants;
  • Modeling and simulation of fracture propagation;
  • Environmental impacts and mitigation strategies of hydraulic fracturing;
  • Real-time monitoring and adaptive fracturing techniques;
  • Chemical, thermal, and gas injection EOR methods;
  • Case studies of successful EOR implementations;
  • Integration of EOR with reservoir management;
  • Advances in drilling technologies and equipment;
  • Drilling optimization and cost reduction strategies;
  • Wellbore stability and control;
  • New materials and techniques for drilling in challenging environments.

We welcome submissions of original research papers, review articles, and case studies that contribute to the understanding and advancement of these critical areas within petroleum and natural gas engineering. This Special Issue aims to compile a comprehensive collection of cutting-edge research that will serve as a valuable resource for researchers, engineers, and practitioners in the field.

Dr. Jiaxue Li
Dr. Pengfei Zhao
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 250 words) can be sent to the Editorial Office for assessment.

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

  • hydraulic fracturing
  • enhanced oil recovery (EOR)
  • drilling technologies
  • reservoir management
  • environmental impact

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Related Special Issue

Published Papers (4 papers)

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Research

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18 pages, 6208 KB  
Article
Enhanced Gas Drainage via Gas Injection Displacement Based on Hydraulic Flushing: Numerical Simulation and Field Test
by Xin Yang, Feiyan Tan and Qingcheng Zhang
Energies 2026, 19(9), 2061; https://doi.org/10.3390/en19092061 - 24 Apr 2026
Viewed by 382
Abstract
Hydraulic flushing is an effective permeability enhancement technology for coal seams in underground coal mines and has been widely applied in several mining areas in China. However, in low-permeability coal seams, gas drainage from hydraulic flushing boreholes often enters a rapid depletion phase, [...] Read more.
Hydraulic flushing is an effective permeability enhancement technology for coal seams in underground coal mines and has been widely applied in several mining areas in China. However, in low-permeability coal seams, gas drainage from hydraulic flushing boreholes often enters a rapid depletion phase, and achieving secondary enhanced drainage remains a critical challenge. To address this issue, this study investigates a synergistic gas drainage technology that combines gas injection displacement with hydraulic flushing. Taking the No. 3 coal seam in the Lu’an mining area of China as the research object, the optimal process parameters of this synergistic technology are systematically determined through numerical simulation and validated by underground field tests. A fully coupled numerical model incorporating the adsorption–desorption–seepage processes of the CH4/N2/O2 ternary gas system is established. The influences of injection spacing and injection pressure on drainage performance are systematically analyzed. Simulation results identify the optimal process parameters as an injection spacing of 3.5 m and an injection pressure of 1.4 MPa. Under these conditions, the relative coal permeability reaches a maximum of 1.06, the permeability enhancement zone fully covers the region between the injection and drainage boreholes, and the coal seam gas content decreases to the critical threshold of 8 m3/t in approximately 235 days. The model is quantitatively validated using 82-day field monitoring data from the synergistic module, with a relative error of approximately 1.1% between the simulated and field-derived recovery ratios. Subsequently, four sets of underground engineering trials—conventional drainage, gas injection displacement alone, hydraulic flushing alone, and the synergistic technology—are conducted in the target coal seam based on the optimized parameters. Statistical analysis of the 82-day field data shows that the synergistic technology achieves a cumulative pure methane volume of 4.83 m3, outperforming conventional drainage by 85.8% (4.83 m3 compared with 2.60 m3), gas injection alone by 23.5% (4.83 m3 compared with 3.91 m3), and hydraulic flushing alone by 52.4% (4.83 m3 compared with 3.17 m3). The mean flow rate of the synergistic module during the injection phase reaches 0.070 ± 0.012 L/min, significantly higher than that of gas injection alone (0.044 ± 0.011 L/min). This study provides economically feasible theoretical and technical support for efficient gas drainage in low-permeability coal seams in underground mines. Full article
(This article belongs to the Special Issue Petroleum and Natural Gas Engineering: 2nd Edition)
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19 pages, 1449 KB  
Article
Study on the Injection Modes and Displacement Characteristics of Chemical Compound Flooding in Heavy Oil Reservoirs After Multiple Cycles of Huff-and-Puff
by Li Zhang, Lei Tao, Guanli Xu and Jiajia Bai
Energies 2026, 19(7), 1728; https://doi.org/10.3390/en19071728 - 1 Apr 2026
Viewed by 421
Abstract
The chemical agent injection modes and displacement characteristics of chemical compound flooding, consisting of a plugging agent, an oil displacement agent, and a viscosity reducer, were investigated by laboratory experiments for target heavy oil reservoirs after multiple cycles of huff-and-puff. The performances of [...] Read more.
The chemical agent injection modes and displacement characteristics of chemical compound flooding, consisting of a plugging agent, an oil displacement agent, and a viscosity reducer, were investigated by laboratory experiments for target heavy oil reservoirs after multiple cycles of huff-and-puff. The performances of the oil displacement agent, viscosity reducer and plugging agent were evaluated, and the formulation and concentration were optimized. The oil displacement effects and displacement characteristics of different injection modes were studied by sand-filled two-pipe models. The experiment results showed that alternating injections of the oil displacement agent and viscosity reducer yielded better results than their mixed injection, and small segments alternating injections achieved the highest recovery. The larger the dosage of the oil displacement agent, the larger the maximum liquid production ratio between the high- and low-permeability layers, but with the smaller the liquid production reverse duration. The larger the dosage of the viscosity reducer, the greater the water cut decrease but the smaller the maximum liquid production ratio. For chemical compound flooding in the Zhong’er block in the Gudao oilfield, the recommended injection mode was 0.1 PV plugging agent + 2000 mg/L of oil displacement agent + 0.5% viscosity reducer, with small segments of the oil displacement agent being followed by a viscosity reducer at an injection slug ratio of 6:4. However, the injection mode depends on the prices of oil and the chemical agent. When prices fluctuate, the chemical agent concentration should be adjusted accordingly. Full article
(This article belongs to the Special Issue Petroleum and Natural Gas Engineering: 2nd Edition)
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13 pages, 1240 KB  
Article
Use of Oil-Containing Sludge to Produce the Oil–Water Profile Control Agent
by Jianzhong Zhu, Wenjie Wei, Yating Ding, Zhequn Pang, Jiaxue Li, Youwei Li and Hualong Yang
Energies 2026, 19(2), 429; https://doi.org/10.3390/en19020429 - 15 Jan 2026
Viewed by 652
Abstract
To address the problems of complex composition, significant property variations, and difficult and costly harmless treatment of oil-contaminated sludge in oil and gas field development, its good compatibility with the formation is leveraged to formulate it with oilfield water into an oil–water profile [...] Read more.
To address the problems of complex composition, significant property variations, and difficult and costly harmless treatment of oil-contaminated sludge in oil and gas field development, its good compatibility with the formation is leveraged to formulate it with oilfield water into an oil–water profile control agent. This reduces the cost of harmless treatment and enables resource utilization of hazardous waste. The properties of oil-contaminated sludge were evaluated experimentally. Suspending agents and stabilizers were selected according to the oil–water profile control agent preparation process, the corresponding agents were prepared, and the system was experimentally tested. The experimental results show that the suspending agent carboxymethyl cellulose (CMC) and partially hydrolyzed polyacrylamide (HPAM), and the dispersant Dodecyl dimethyl betaine (BS-12) are used to prepare oil–water profile control agent based on the selected sulfonated mud oily sludge and ground system oily sludge. The optimal formulation of profile control agent is as follows: (1) 50% ground system oily sludge +50% oilfield produced water + 0.2% CMC + 1.0% BS-12; (2) 50% sulfonated mud system oily sludge +50% oilfield produced water + 0.1% HPAM + 1.0% BS-12. The preparation of a profile control agent from oily sludge is a viable low-cost resource treatment strategy for oily sludge, which is of great significance for the environmentally friendly treatment of oil and gas field development. Full article
(This article belongs to the Special Issue Petroleum and Natural Gas Engineering: 2nd Edition)
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Review

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23 pages, 2723 KB  
Review
Assessment Methods for DC Stray Current Corrosion Hazards in Underground Gas Pipelines: A Review Focused on Rail Traction Systems
by Krzysztof Żakowski, Michał Szociński and Stefan Krakowiak
Energies 2025, 18(21), 5570; https://doi.org/10.3390/en18215570 - 23 Oct 2025
Cited by 1 | Viewed by 2027
Abstract
Stray currents leaking from electrified DC rail systems cause the greatest corrosion risk to underground metal gas pipelines and can lead to pipeline wall perforation in a very short time. Leakage and gas explosion, and other direct and indirect effects, can even disrupt [...] Read more.
Stray currents leaking from electrified DC rail systems cause the greatest corrosion risk to underground metal gas pipelines and can lead to pipeline wall perforation in a very short time. Leakage and gas explosion, and other direct and indirect effects, can even disrupt the stability of the energy system. Maintaining the reliability of gas pipelines, therefore, requires protecting them against corrosion caused by stray currents. It is therefore necessary to conduct field studies to identify sections of gas pipelines at risk and where protective installations should be installed. The paper discusses the most important field methods for assessing the risk of stray currents to gas pipelines: the potential of rail traction relative to ground, electric field gradients in the ground associated with stray current flow, correlation of gas pipeline potential and voltage of pipeline vs. the rail, and time-frequency analysis of the pipeline and rail potentials. A typical application case for each method is indicated, and the advantages and disadvantages of each research technique are identified. The criterion for selecting methods for this review was a short measurement duration (tens of minutes), after which it is possible to determine the level of the hazard to the gas pipeline caused by stray currents in the examined location. This is why these methods have an advantage over other research techniques that require long-term monitoring or exposure of probes or sensors. The review will be useful for cathodic protection personnel involved in the operation of gas pipelines and may be helpful in developing new methods for assessing the impact of stray currents. Full article
(This article belongs to the Special Issue Petroleum and Natural Gas Engineering: 2nd Edition)
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