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Processes
Special Issues
Advanced Technologies for Efficient Oil and Gas Production and Recovery...
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Advanced Technologies for Efficient Oil and Gas Production and Recovery Enhancement

A special issue of Processes (ISSN 2227-9717). This special issue belongs to the section "Petroleum and Low-Carbon Energy Process Engineering".

Deadline for manuscript submissions: 30 November 2026 | Viewed by 780

Editors

Dr. Xingyuan Liang

E-Mail Website
Guest Editor
State Key Laboratory of Petroleum Resources and Prospecting, China University of Petroleum (Beijing), Beijing 102249, China
Interests: gas lift; multiphase flow in wellbores; plunger lift; imbibition
Special Issues, Collections and Topics in MDPI journals
Prof. Dr. Guoqing Han

E-Mail Website
Guest Editor
Petroleum Engineering, China University of Petroleum, Beijing 102249, China
Interests: artificial lift; multiphase flow; gas lift; productivity; complex well
Special Issues, Collections and Topics in MDPI journals
Dr. Xiaojun Wu

E-Mail Website
Guest Editor
School of Petroleum and Natural Gas Engineering, Changzhou University, Changzhou 213164, China
Interests: shale oil and gas; carbon dioxide; mass transfer
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

As oil and gas fields enter the middle and late stages of development, challenges such as production decline, high water cut, and gas well liquid loading severely restrict operational efficiency. It is urgent to develop new technologies to stabilize and increase production. Meanwhile, intelligent and digital methods are rapidly advancing in petroleum engineering, offering new pathways to solve these problems. This Special Issue aims to gather cutting-edge research and practical applications in this field.

The topics include, but are not limited to, the following:

  • Water control and profile modification for mature oil wells;
  • Liquid unloading and production stabilization in gas wells;
  • Artificial lift optimization for production enhancement;
  • EOR technologies for improved oil recovery;
  • Intelligent monitoring and optimization for oil and gas production.

Dr. Xingyuan Liang
Prof. Dr. Guoqing Han
Dr. Xiaojun Wu
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-anonymized peer-review process. A guide for authors and other relevant information for submission of manuscripts is available on the Instructions for Authors page. Processes 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.

Keywords

  • gas well deliquification
  • wellbore multiphase flow
  • artificial lift performance
  • gas lift efficiency
  • plunger lift production

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Further information on MDPI's Special Issue policies can be found here.

Published Papers (2 papers)

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Research

24 pages, 5840 KB  
Article
A Multi-Constraint Integrated Zoning Method for Redevelopment of Mature Shale Gas Well Areas
by Xiaojun Yuan, Muyang Zhang, Zhanhong Su, Huan Cui, Chenggang Xian, Caoxiong Li, Yingxue Sun, Hangyuan Li and Yang Zhao
Processes 2026, 14(13), 2130; https://doi.org/10.3390/pr14132130 - 30 Jun 2026
Abstract
Mature shale gas areas commonly retain substantial remaining resources after long-term depletion, but their redevelopment potential is governed by pressure redistribution, present-day stress evolution, natural-fracture stability, and target accessibility. Taking the HuangJinBa YS108 shale gas area as an example, this study proposes an [...] Read more.
Mature shale gas areas commonly retain substantial remaining resources after long-term depletion, but their redevelopment potential is governed by pressure redistribution, present-day stress evolution, natural-fracture stability, and target accessibility. Taking the HuangJinBa YS108 shale gas area as an example, this study proposes an integrated redevelopment zoning workflow that couples geological conditions, geomechanical constraints, and fracture-slip risk. Two types of remaining targets are identified: inter-well remaining resources and wellbore-control blind-spot resources. A geological-condition evaluation index (GCEI) is then constructed using remaining gas content, effective reservoir thickness, and remaining pressure. The zoning results are further constrained by the Anderson stress-regime index, horizontal stress difference, maximum horizontal stress orientation, and a Mohr–Coulomb-based natural-fracture-slip-risk index. Results indicate that L113 and L112 are the main depleted layers, whereas L114, L111, and the Wufeng Formation retain further redevelopment potential. Favorable zones are mainly distributed around platforms H24, H1, H3, H23, H13, and eastern H20. Long-term depletion reduces the minimum horizontal stress in densely developed areas and generally improves fracture stability, although local fracture intersections still present elevated slip risk. The final zoning provides a practical basis for redevelopment decision-making: platforms H24, H1, H3, H23, H13, and eastern H20 can be prioritized for near-term screening; inter-well targets should be developed using conservative infill strategies with controlled fracture length; and wellbore-control blind-spot targets can be stimulated more intensively under controllable fracture-slip risk. Full article
(This article belongs to the Special Issue Advanced Technologies for Efficient Oil and Gas Production and Recovery Enhancement)
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25 pages, 13115 KB  
Article
Production State Identification of Offshore High-Water-Rate Gas Wells Based on Dynamic Pressure Profile Calibration and Nodal Analysis
by Xiaoyou Du, Xiaolong Xiang, Weitao Zhu, Jifei Yu, Guoqing Han and Wenbo Jiang
Processes 2026, 14(11), 1743; https://doi.org/10.3390/pr14111743 - 27 May 2026
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Abstract
Offshore high-water-rate gas wells can often sustain stable production for a considerable period after liquid first appears at the wellhead. Unlike conventional onshore gas wells with relatively low liquid production, these wells can remain in stable production during the middle and late production [...] Read more.
Offshore high-water-rate gas wells can often sustain stable production for a considerable period after liquid first appears at the wellhead. Unlike conventional onshore gas wells with relatively low liquid production, these wells can remain in stable production during the middle and late production stages even when the gas velocity in the wellbore has fallen far below the critical value predicted by conventional liquid-carrying criteria. Under such conditions, the wellbore flow pattern commonly shifts from annular mist flow to churn flow and slug flow, and liquid transport becomes governed by a dynamic balance jointly controlled by pressure differential and gas entrainment. As a result, conventional critical liquid-carrying theory alone is no longer sufficient for accurate production state identification. To address this issue, this study proposes a production state identification method for offshore high-water-rate gas wells based on dynamic pressure profile calibration and nodal analysis. In this method, the wellbore pressure profile serves as the key link between outflow capacity and production state evaluation. Measured data from flowing pressure tests are used to calibrate the pressure profile within the selected multiphase flow correlation by introducing two calibration coefficients, namely the liquid holdup calibration coefficient and the two-phase friction calibration coefficient. Gaussian process regression is then applied to model the temporal evolution of the calibration coefficients, generate their fitted trajectories, and predict their values at the next time step. By using the predicted calibration coefficients to recalibrate the pressure profile, dynamic calibration of the wellbore pressure profile is achieved. Field applications to four offshore high-water-rate gas wells show that the calibrated pressure profiles are in closer agreement with the measured pressure points. The accuracy of production-state identification is also significantly improved, and the gas production rates calculated from calibrated nodal analysis are closer to the values reported in daily production records than those obtained before calibration. These results demonstrate that the proposed method effectively improves both wellbore pressure profile prediction and production-state identification for offshore high-water-rate gas wells. The study provides a practical method for production state evaluation and production management of offshore high-water-rate gas wells during the middle and late stages of field development. Full article
(This article belongs to the Special Issue Advanced Technologies for Efficient Oil and Gas Production and Recovery Enhancement)
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