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A special issue of Processes (ISSN 2227-9717).

Deadline for manuscript submissions: 30 June 2026 | Viewed by 8084

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Dr. Jianbo Zhang

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Guest Editor

School of Petroleum Engineering, China University of Petroleum (East China), Qingdao 266580, China
Interests: offshore oil and gas engineering; natural gas hydrate development; deepwater flow assurance; multiphase flow; CO₂ storage
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Dr. Xiaohui Sun

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Guest Editor

College of Computer Science and Technology, China University of Petroleum (East China), Qingdao, China
Interests: multiphase flow intelligent simulation; wellbore pressure control; deep learning algorithm; intelligent development of oil and gas fields
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Dr. Wenqiang Lou

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Guest Editor

School of Petroleum Engineering, Yangtze University, Wuhan, China
Interests: multiphase flow in wellbore; wellbore pressure control; drilling hydraulics; intelligent drilling monitoring
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

Oil and gas resources are important pillars for the sustainable development of human society and its economy. Marine and deep strata contain abundant oil and gas resources, and much oil and gas reserves in marine and deep strata have been newly discovered in recent years. With the rapid development of the global economy's energy demand, oil and gas development is accelerating its pace towards marine and deep strata. However, the environment and formation conditions in marine and deep strata are complex, and along with many unknown factors, pose significant challenges in the development of oil and gas resources. Specific directions include efficient drilling, pressure control, flow assurance, efficient production increase, intelligence development, and environmental safety. The lack of oil and gas development technology in marine and deep strata is an important factor limiting a country's economic development, especially in countries with limited oil and gas resources. Therefore, it is necessary to establish safe and efficient oil and gas development technologies for marine and deep strata to provide support for sustainable global economic development and energy security.

This Special Issue explores oil and gas development technologies in marine and deep strata, with a focus on the roles of new theories, advanced methods, important technology, classic cases, and policy recommendations. This Special Issue calls for active submissions from researchers in different disciplines, providing valuable guidance for the safe and efficient development of marine and deep strata oil and gas.

You may choose our Joint Special Issue in Sustainability.

Dr. Jianbo Zhang
Dr. Xiaohui Sun
Dr. Wenqiang Lou
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. 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

oil and gas development
marine
deep strata
drilling
multiphase flow
flow assurance
pressure control
production increase
intelligence development
environmental safety

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Published Papers (9 papers)

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Research

19 pages, 4182 KB

Open AccessArticle

Experimental Evaluation of Sealing Performance at the First and Second Interfaces of Cement Sheath Under Cyclic Loading

by Qiqi Ying, Lei Wang, Zhenhui Bi, Yintong Guo, Yuxiang Jing and Chuanfu Sun

Processes 2026, 14(5), 805; https://doi.org/10.3390/pr14050805 - 28 Feb 2026

Viewed by 227

Abstract

With the development of unconventional oil and gas resources (such as shale gas and tight oil/gas), the widespread application of multistage fracturing technology has significantly increased the difficulty of wellbore integrity maintaining. The cement sheath serves as the core barrier for preserving wellbore integrity, particularly at the first interface (cement–casing) and the second interface (cement–formation). The high temperature, high pressure, and cyclic dynamic loading imposed by multistage fracturing represent severe challenges to the integrity of cement sheath. To simulate underground conditions realistically, a high-temperature, complex stress path loading system coupled with real-time gas flow monitoring was developed. Using this system, gas leakage monitoring and displacement-controlled cyclic loading tests were conducted on cement–steel (simulating the first interface) and cement–shale (simulating the second interface) composite specimens. It focused on investigating the effects of different temperatures, cyclic stress levels, and cycle counts on the sealing performance of the cement–steel and cement–shale composites. The findings reveal that elevated temperatures significantly degrade cement properties and accelerate damage accumulation. Cyclic stress levels and cycle counts are core drivers of interface fatigue failure, exhibiting synergistic destructive effects with temperature. The first interface is more prone to seal failure due to material property differences and a relatively high stress level. This research elucidates the cumulative damage mechanism underlying interfacial seal failure. It is of significant engineering implications for enhancing well safety and development efficiency. Full article

(This article belongs to the Special Issue Advanced Research on Marine and Deep Oil & Gas Development)

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21 pages, 4050 KB

Open AccessArticle

Mechanical Stability Evaluation Method and Application for Subsea Christmas Tree-Wellhead Systems Considering Seismic and Corrosion Effects

by Xuezhan Zhao, Guangjin Chen, Yi Hong, Shuzhan Li, Zhiqiang Hu, Yongqi Ma, Xingpeng Zhang, Qian Xiang, Xingshang Chen and Bingzhen Gao

Processes 2026, 14(3), 431; https://doi.org/10.3390/pr14030431 - 26 Jan 2026

Viewed by 313

Abstract

To address the failure risks associated with long-term service of subsea Christmas tree-wellhead systems under the complex marine environment of the South China Sea, a multi-factor coupled mechanical analysis method is proposed to evaluate the system’s mechanical characteristics and ensure the safety of deepwater oil and gas production. A dynamic model of lateral vibration under seismic loading is established, considering the combined effects of earthquakes, ocean currents, and seabed soil resistance. Based on the actual operating parameters of a well in the Lingshui area of the South China Sea, a three-dimensional finite element model of the subsea Christmas tree-wellhead assembly was developed in ABAQUS 2023. The combined effects of ocean currents, seismic loading, and corrosion over long-term service were simulated to compute and analyze the distributions of stress, bending moment, and associated failure risk. The results indicate that, under a once-in-a-century current combined with seismic waves of intensity V–VI, the system risk remains controllable. However, when the seismic intensity exceeds level VII, the maximum stress and bending moment reach 324.9 MPa and 6.02 MN·m, respectively, surpassing the allowable limits for an X56-grade surface conductor. Considering corrosion effects over a 25-year service life, the extreme stress values increase by 1–5% while the bending moment increases slightly; corrosion significantly amplifies the system’s failure risk. An analysis of the mudline burial height of the subsea wellhead during long-term service shows that, within a range of 1–7 m, variations in system loading are minimal. Based on the mechanical characteristics analysis, it is recommended that the design of subsea Christmas trees and wellheads incorporate regional seismic history, specify X56-grade surface conductors to mitigate corrosion effects, and install leakage-monitoring devices at critical locations to ensure the long-term service safety of the subsea Christmas tree-wellhead system. Full article

(This article belongs to the Special Issue Advanced Research on Marine and Deep Oil & Gas Development)

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24 pages, 9651 KB

Open AccessArticle

H₂/CH₄ Competitive Adsorption of LTA Zeolite: Effects of Cations, Si/Al Ratio, Adsorption Temperature, and Pressure

by Xue Zhang, Jianfeng Tang and Hui Liu

Processes 2026, 14(2), 387; https://doi.org/10.3390/pr14020387 - 22 Jan 2026

Viewed by 315

Abstract

The efficient separation of H₂ from CH₄ is crucial for hydrogen purification from industrial off-gases using pressure swing adsorption (PSA). In this study, the competitive adsorption behavior of H₂/CH₄ on LTA zeolites was systematically investigated via grand canonical Monte Carlo (GCMC) simulations, with a focus on the effects of cation type (Na⁺, Li⁺, Ca²⁺, Mg²⁺), Si/Al ratio (1–1.5), temperature (298–318 K), and pressure (0.2–2 MPa). The results reveal that CH₄ favors β-cages as excellent adsorption sites with high population density, followed by the regions adjacent to the cations or framework oxygen atoms of the eight-membered rings. In contrast, H₂ is uniformly distributed throughout all the channels. Cations with higher valence and smaller ionic radii (e.g., Mg²⁺) enhance CH₄ adsorption capacity and diffusion more effectively than monovalent or larger cations. Increasing the Si/Al ratio reduces cation content and exposes more framework oxygen atoms, particularly those in Si–O–Si environments, which improve CH₄ adsorption. Elevated temperature weakens CH₄ adsorption while promoting H₂ diffusion and pore occupancy. Although higher pressure increases the uptake of both gases, H₂ adsorption rises more substantially and distributes more widely, leading to a decrease in CH₄/H₂ selectivity. Full article

(This article belongs to the Special Issue Advanced Research on Marine and Deep Oil & Gas Development)

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23 pages, 4205 KB

Open AccessArticle

A Novel Predictive Model for Drilling Fluid Rheological Parameters Across Wide Temperature–Pressure Ranges Using Symbolic Regression Algorithm

by Wang Chen, Jun Li, Hongwei Yang, Geng Zhang, Biao Wang, Gonghui Liu, Zhaoyu Shen and Hui Ji

Processes 2026, 14(2), 386; https://doi.org/10.3390/pr14020386 - 22 Jan 2026

Viewed by 252

Abstract

Accurate prediction of drilling fluid rheological parameters under high-temperature and high-pressure (HTHP) conditions is critical for reliable drilling hydraulics and wellbore pressure control in deep and ultra-deep wells. However, most existing empirical and semi-empirical rheological models are developed for limited temperature–pressure ranges and specific fluid formulations, which restrict their applicability and accuracy under HTHP conditions. In this study, systematic rheological experiments were conducted on multiple drilling fluid systems over wide temperature–pressure ranges (20–200 °C and 0.1–200 MPa). Based on the experimental data, a unified predictive model for key rheological parameters was developed using a symbolic regression (SR) algorithm. The model performance was evaluated using standard statistical metrics and compared with commonly used conventional models. Compared with conventional models, the proposed model shows stronger applicability for predicting the rheological parameters of the investigated oil-based and water-based drilling fluids over a wider temperature–pressure range. It effectively overcomes the limitations of existing models under HTHP conditions (150–200 °C and 80–200 MPa) and demonstrates improved prediction accuracy and robustness for both high- and low-density drilling fluids. The overall prediction errors are generally within approximately 10%. The results indicate that the proposed unified model provides a reliable and computationally efficient tool for predicting drilling fluid rheological parameters under HTHP conditions, facilitating its integration into wellbore hydraulics, wellbore pressure, and equivalent circulating density calculations in deep and ultra-deep well applications. Full article

(This article belongs to the Special Issue Advanced Research on Marine and Deep Oil & Gas Development)

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19 pages, 1685 KB

Open AccessArticle

Study on Two-Phase Flow Behavior and Analysis of Influencing Factors Based on Unsteady Oil–Water Relative Permeability Experiment

by Liqiang Dong, Depeng Dong, Wenqiang Lou and Jie Cao

Processes 2026, 14(2), 346; https://doi.org/10.3390/pr14020346 - 19 Jan 2026

Viewed by 353

Abstract

Late-stage sandstone reservoirs often exhibit flow behavior markedly different from early performance, reducing recovery. This study quantifies two-phase flow in Jilin Oilfield sandstone cores to support production optimization. An oil–water displacement apparatus was built and unsteady-state relative-permeability tests were performed on core plugs from multiple well blocks. Permeability, pressure gradient, water saturation, and displacement efficiency were tracked over a range of injection multiples. Water-phase relative-permeability curves classify three seepage types: concave-up (12 cores, 2.10–46.17 mD), linear (7 cores, 1.58–12.23 mD), and concave-down (3 cores, 8.74–30.73 mD). Permeability is strongly negatively correlated with irreducible water saturation (R² = 0.84) and positively correlated with residual oil saturation (R² = 0.58), two-phase flow interval (R² = 0.51), and movable oil saturation (R² = 0.89); other relationships are weak. An increasing pressure gradient markedly improves displacement efficiency in low-permeability cores. Higher injection multiples further raise displacement efficiency across all permeability classes, but gains diminish with increasing permeability. Displacement efficiency also increases with water cut when used as a flooding-stage indicator in these unsteady-state tests. Full article

(This article belongs to the Special Issue Advanced Research on Marine and Deep Oil & Gas Development)

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22 pages, 9537 KB

Open AccessArticle

Study on Wellbore Stability of Shale–Sandstone Interbedded Shale Oil Reservoirs in the Chang 7 Member of the Ordos Basin

by Yu Suo, Xuanwen Kong, Heng Lyu, Cuilong Kong, Guiquan Wang, Xiaoguang Wang and Lingzhi Zhou

Processes 2025, 13(5), 1361; https://doi.org/10.3390/pr13051361 - 29 Apr 2025

Cited by 4 | Viewed by 988

Abstract

Wellbore instability is a major constraint in large-scale shale oil extraction. This study focuses on the shale–sandstone interbedded shale oil reservoirs in the Chang 7 area, delving into the evolutionary principles governing wellbore stability in horizontal drilling operations within these formations. A geological feature analysis of shale–sandstone reservoir characteristics coupled with rigorous mechanical experimentation was undertaken to investigate the micro-mechanisms underpinning wellbore instability. The Mohr–Coulomb failure criterion applicable to sandstone and the multi-weakness planes failure criterion of shale were integrated to analyze the stress distribution of surrounding rocks within horizontal wells, facilitating the computation of collapse pressure and fracture pressure. A finite element model of wellbore stability in shale–sandstone horizontal drilling was established, and then we conducted a comprehensive analysis of the impacts of varying elastic moduli, Poisson’s ratio, and in-situ stress on wellbore stability. The findings reveal that under varying confining pressures, the predominant failure mode observed in most sandstone samples is characterized by inclined shear failure, coupled with a reduced incidence of crack formation. The strength of shale escalates proportionally with increasing confining pressure, resulting in a reduced susceptibility to failure along its inherent weak planes. This transition is characterized by a gradual shift from the prevalent mode of longitudinal splitting towards inclined shear failure. As the elastic modulus of shale rises, the discrepancy between circumferential and radial stresses decreases. In contrast, with the increasing elastic modulus of sandstone, the gap between circumferential and radial stresses widens, potentially inducing potential instabilities in the wellbore. An increase in sandstone’s Poisson’s ratio corresponds to a proportional increase in the difference between circumferential and radial stresses. Under reverse fault stress regimes, wellbore collapse and instability are predisposed to occur. Calculations of collapse pressure and fracture pressure reveal that the safety density window is minimized at the interface between shale and sandstone, rendering it susceptible to wellbore instability. These research findings offer significant insights for the investigation of wellbore stability in interbedded shale–sandstone reservoirs contributing to the academic discourse in this field. Full article

(This article belongs to the Special Issue Advanced Research on Marine and Deep Oil & Gas Development)

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22 pages, 8876 KB

Open AccessArticle

Efficient Design of Three-Dimensional Well Trajectories with Formation Constraints and Optimization

by Xueying Wang, Jie Zheng, Jianmin Wang, Yibing Yu, Xi Wang and Feifei Zhang

Processes 2025, 13(4), 1215; https://doi.org/10.3390/pr13041215 - 17 Apr 2025

Cited by 1 | Viewed by 1288

Abstract

Current methods for designing three-dimensional trajectories rarely account for complex formation constraints, focusing primarily on geometric relationships. However, trajectory adjustments are often necessary during drilling operations. These field adjustments typically lack systematic optimization, resulting in suboptimal trajectories. This study introduces a novel trajectory optimization framework that integrates formation fitness for curve construction and proactive anti-collision trajectory adjustment (PACTA). The framework begins by incorporating PACTA and optimizing the initial trajectory to minimize total measured depth (TMD) using a genetic algorithm. Subsequently, a second optimization phase identifies curve sections passing through formations with low build-up fitness, automatically splitting them into combinations of curves and straight lines. Dynamic trajectory equations are then constructed based on these adjustments, and the final trajectory is optimized accordingly. Case studies demonstrate that the proposed method effectively adjusts curve positions in the presence of multiple formations with low build-up fitness while avoiding wellbore collisions. The approach achieves an average 10% reduction in total drilling time when minimizing TMD and an average 19.7% reduction in drillstring torque when torque minimization is prioritized. This new trajectory design method is expected to significantly reduce well construction costs. Full article

(This article belongs to the Special Issue Advanced Research on Marine and Deep Oil & Gas Development)

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12 pages, 11071 KB

Open AccessArticle

Experimental Study on Combustion Characteristics of Methane Vertical Jet Flame

by Yudan Peng, Jing Yu, Weifeng Chen, Chen Hao, Jiawei Zhang, Guangming Fu and Baojiang Sun

Processes 2025, 13(4), 1207; https://doi.org/10.3390/pr13041207 - 16 Apr 2025

Cited by 3 | Viewed by 1179

Abstract

A jet flame is a common type of flame in fires in the oil and gas industries. At present, research on jet flames is still not comprehensive enough. To systematically investigate the combustion characteristics of vertical methane jet flames, experiments were conducted on vertical methane jet flames, supplementing the existing experimental data on jet fires. The study reveals variations in the flame shape, center temperature, and thermal radiation with different flow rates and nozzle diameters, and the mechanisms of change in the flame center temperature and thermal radiation are discussed. The results show that increasing the gas flow rates and nozzle diameters led to a greater flame height and width. Along the flame axis, the temperature initially rose and then decreased with an increasing vertical distance from the nozzle. For smaller nozzle diameters, the flame temperature increased with the flow rate beyond the peak temperature point. Additionally, higher flow rates and larger nozzle diameters raised the height at which the maximum thermal radiation occurred. The thermal radiation near the flame’s top exceeded that in the middle, while minimal changes were observed near the base. The jet flame’s lift-off height and shape significantly influenced the distribution of the centerline temperature and thermal radiation. These findings provide valuable insights for the effective management and control of gas jet fires. Full article

(This article belongs to the Special Issue Advanced Research on Marine and Deep Oil & Gas Development)

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26 pages, 8635 KB

Open AccessArticle

Quantitative Analysis and Modeling of Transient Cuttings Transport Impact on Drill String Mechanics in Extended Reach Drilling

by Jianbo Xiang, Xi Wang, Wenqiang Lou, Xueying Wang, Chi Zhao and Feifei Zhang

Processes 2025, 13(1), 35; https://doi.org/10.3390/pr13010035 - 27 Dec 2024

Viewed by 2403

Abstract

Cuttings beds in horizontal wells significantly affect the frictional torque and drag along the drill string; however, their quantification and modeling have been relatively underexplored. To gain deeper insights into the impact mechanisms of the cuttings bed distribution on drilling mechanics, this study establishes a model linking the cuttings bed height with variations in axial and tangential forces on the drill string through experimental investigations. By integrating this model with previously developed transient cuttings transport and torque–drag models, a coupled transient hole cleaning and drill string mechanics model is constructed. This comprehensive model simulates the dynamic distribution of cuttings along the entire well trajectory and its influence on the drill string torque and drag. The results reveal that accumulated cuttings significantly reduce the weight on bit (WOB), increase the drill string torque, and cause problems related to a high equivalent circulation density (ECD). For long horizontal sections, the key to achieving effective hole cleaning lies in optimizing the design of the tripping circulation time to ensure that all cuttings are removed from the wellbore. Using the proposed coupled model, a methodology is developed to minimize the tripping circulation time by solving optimization problems within a constrained 2D domain, providing scientific guidance for drilling operations. The findings demonstrate that dynamically managing the cuttings distribution in the wellbore can significantly mitigate issues arising from insufficient hole cleaning, thereby ensuring drilling safety and efficiency. This study provides a scientific foundation for the optimized design of long horizontal well drilling operations and highlights the critical role of cuttings management in enhancing hole cleaning performance and mitigating drilling risks. Full article

(This article belongs to the Special Issue Advanced Research on Marine and Deep Oil & Gas Development)

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