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Advanced Approaches in Drilling Processes and Enhanced Oil Recovery
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Advanced Approaches in Drilling Processes and Enhanced Oil Recovery

A Special Issue of Processes (ISSN 2227-9717) belonging to the section "Process Control, Modeling and Optimization".

Deadline for manuscript submissions: 30 September 2026 | Viewed by 3133

Editor

Dr. Alireza Kazemi

E-Mail Website
Guest Editor
Department of Petroleum and Chemical Engineering, College of Engineering, Sultan Qaboos University, Muscat, Oman
Interests: enhanced oil recovery; reservoir modelling and simulation; carbon storage
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

The global energy demand continues to grow, driven by rising populations and accelerating economic development. This growing demand puts increasing pressure on conventional oil production techniques, which often face limitations due to declining reservoir pressures, complex geological settings, and aging infrastructure. To address these challenges, the industry is turning to innovative drilling technologies and Enhanced Oil Recovery (EOR) methods to unlock additional hydrocarbon resources and maximize reservoir performance.

This Special Issue aims to bring together cutting-edge research that advances both drilling processes and EOR technologies, highlighting the synergy between these two critical areas in petroleum engineering. It will cover breakthroughs in experimental investigations, numerical modeling, field applications, and the integration of smart technologies such as AI and machine learning.

We invite researchers to submit original articles and reviews on topics including, but not limited to, the following:

  • Smart Drilling Systems and Automation;
  • Drilling Fluids and Wellbore Stability;
  • Horizontal and Multilateral Drilling Techniques;
  • Real-Time Monitoring and Optimization in Drilling;
  • Smart Water Flooding;
  • Nanotechnology Applications in EOR;
  • CO₂-based EOR Methods;
  • Microbial and Chemical EOR;
  • Low-Salinity and Hybrid EOR Techniques;
  • EOR in Shale and Tight Formations;
  • AI and Data-Driven Approaches in Drilling and EOR;
  • Environmentally Friendly and Sustainable EOR Methods.

This Special Issue will showcase the latest advancements shaping the future of oilfield development, offering insights into more efficient, sustainable, and intelligent solutions for maximizing hydrocarbon recovery. We encourage contributions from academia, research institutions, and industry professionals who are pushing the boundaries of innovation in drilling and EOR.

Dr. Alireza Kazemi
Guest Editor

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

  • drilling optimization
  • smart drilling technologies
  • enhanced oil recovery (EOR)
  • CO2-EOR
  • low-salinity waterflooding
  • smart water flooding
  • nanotechnology in EOR
  • microbial EOR
  • artificial intelligence in EOR
  • reservoir simulation

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

Published Papers (4 papers)

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Research

34 pages, 2737 KB  
Article
A Geomechanically Augmented Neural Network with Heterogeneity-Adaptive Data Splitting, Systematic Hyperparameter Optimization, and LSTM-FCNN Hybrid Architecture for Rate of Penetration (ROP) Prediction
by Ahmed S. Alhalboosi and Mohammed A. Khamis
Processes 2026, 14(14), 2281; https://doi.org/10.3390/pr14142281 - 13 Jul 2026
Viewed by 374
Abstract
The complex, heterogeneous nature of many subsurface environments makes accurate Rate of Penetration (ROP) prediction both critical and challenging for achieving drilling efficiency, cost control, and operational safety. Although artificial intelligence has demonstrated strong potential in extracting nonlinear patterns from drilling and well-log [...] Read more.
The complex, heterogeneous nature of many subsurface environments makes accurate Rate of Penetration (ROP) prediction both critical and challenging for achieving drilling efficiency, cost control, and operational safety. Although artificial intelligence has demonstrated strong potential in extracting nonlinear patterns from drilling and well-log data, its application to heterogeneous formations remains limited by: (i) overreliance on operational parameters that lack formation-physics context, (ii) rigid train–test splits that ignore geological variability, and (iii) heuristic hyperparameter selection practices that are not reproducible. This study presents a geomechanically augmented deep learning framework applied to two vertical wells in a Middle East carbonate-clastic field (Well A: 9375 records, 1000–3370 m; Well B: 4443 records, 1945–3131 m). Five contributions are introduced: (1) a physics-informed input space integrating lithology-specific geomechanical properties (UCS, CCS, Young’s modulus, shear modulus, friction angle), validated against core measurements (R2 = 0.79–0.95); (2) a heterogeneity-adaptive train–test partitioning strategy demonstrating that formation complexity, rather than a fixed universal ratio, governs the optimal split; (3) a residual Fully Connected Neural Network (FCNN) with Swish activation and systematic hyperparameter sensitivity analysis; (4) a rigorous preprocessing pipeline comprising 99th-percentile Winsorization, interaction-term feature engineering (WOB × CCS, RPM × UCS), Lasso selection, Z-score normalization, and Gaussian noise augmentation, with all transforms fitted exclusively on training data to prevent leakage; and (5) a hybrid LSTM-FCNN that processes depth-ordered sequences via Savitzky–Golay denoising and a ten-step sliding window. The standalone FCNN achieved R2 = 0.8641 (Well A) and R2 = 0.9062 (Well B). The LSTM-FCNN improved intra-well accuracy to R2 = 0.9877 and R2 = 0.9551 and resolved a severe cross-well transfer asymmetry (B → A: R2 = 0.0388 for FCNN versus R2 = 0.8217 for LSTM-FCNN; A → B: R2 = 0.8963), confirming that depth-sequential modeling captures transferable formation patterns across contrasting lithological profiles. Full article
(This article belongs to the Special Issue Advanced Approaches in Drilling Processes and Enhanced Oil Recovery)
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23 pages, 5494 KB  
Article
Preparation and Performance Evaluation of a Core–Shell Nanosilica-Based Plugging Agent for High-Temperature Oil-Based Drilling Fluids
by Bo Zhao, Wei’an Huang and Junyi Liu
Processes 2026, 14(13), 2097; https://doi.org/10.3390/pr14132097 - 27 Jun 2026
Viewed by 408
Abstract
Maintaining wellbore stability in deep and ultra-deep formations demands plugging agents capable of sealing nano- to micro-scale pores under high-temperature conditions. A core–shell nano-plugging agent (CSP) was synthesized via emulsion polymerization using KH-570-modified nano-SiO2 as the rigid core and a poly(styrene-co-butyl acrylate-co-methyl [...] Read more.
Maintaining wellbore stability in deep and ultra-deep formations demands plugging agents capable of sealing nano- to micro-scale pores under high-temperature conditions. A core–shell nano-plugging agent (CSP) was synthesized via emulsion polymerization using KH-570-modified nano-SiO2 as the rigid core and a poly(styrene-co-butyl acrylate-co-methyl methacrylate) terpolymer as the deformable shell. CSP particles had a mean diameter of 196.5 nm (polydispersity index, PDI = 0.183) and an onset decomposition temperature of 342 °C. Compatibility tests at 180 °C confirmed that 3 wt% CSP caused no adverse changes in the rheology or emulsion stability of the oil-based drilling fluid (OBM). At 180 °C, CSP reduced the high-temperature high-pressure (HTHP) filtrate loss by 64.4% and the permeability plugging apparatus (PPA) filtrate loss by 66.1%. Sand-disk tests elevated the breakthrough pressure from 1.5 to 9.2 MPa. Core displacement on sandstone cores achieved a plugging rate of 98.30%, and pressure transmission tests on natural shale cores extended the 50% equalization time by 7.8-fold. Comparative evaluation confirmed that the core–shell architecture consistently outperformed nano-SiO2 alone, polymer alone, and their physical blend. Low-temperature N2 adsorption provided direct evidence of pore sealing, with the treated-shale Brunauer–Emmett–Teller (BET) surface area and total pore volume reduced by about 62% (12.6 to 4.8 m2/g and 0.0325 to 0.0121 cm3/g, respectively). Scanning electron microscopy of the shale surface before and after treatment further provided direct visual evidence of pore sealing, showing the open, porous matrix being converted into a dense, compacted filter cake. Filter-cake thickness measurements are consistent with a proposed three-stage plugging mechanism—bridging, deformation filling, and thermal compaction—driven by the complementary roles of the rigid core and the deformable shell. These findings indicate that CSP merits further evaluation as a high-temperature plugging agent for wellbore stabilization in deep shale formations. Full article
(This article belongs to the Special Issue Advanced Approaches in Drilling Processes and Enhanced Oil Recovery)
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31 pages, 9998 KB  
Article
Analysis of Impact Rock-Breaking Characteristics and Temperature Field of PDC Cutter
by Zebing Wu, Zihao Zhang, Yifei Lin, Zhe Yan and Kenan Liu
Processes 2026, 14(5), 807; https://doi.org/10.3390/pr14050807 - 28 Feb 2026
Cited by 1 | Viewed by 878
Abstract
Polycrystalline diamond compact (PDC) bits often experience localized heating during impact rock breaking in complex formations, resulting in reduced service life and lower drilling efficiency. An optimized structural design of PDC cutters can significantly enhance bit performance, mitigate thermal concentration, and extend operational [...] Read more.
Polycrystalline diamond compact (PDC) bits often experience localized heating during impact rock breaking in complex formations, resulting in reduced service life and lower drilling efficiency. An optimized structural design of PDC cutters can significantly enhance bit performance, mitigate thermal concentration, and extend operational longevity. Inspired by previous work on PDC cutter surface topography, five saw-type tooth-shaped cutter designs—featuring one to five saw-type teeth were developed. To evaluate their rock-breaking effectiveness and identify the optimum design, the impact-induced rock fragmentation processes of these cutters were compared using the finite element method. Key indicators, including cutting force, mechanical specific energy (MSE), and cutter surface temperature, were analyzed to determine the superior tooth configuration. Among the five designs, the four-saw-tooth cutter induced the most pronounced stress concentration in the rock. Its optimized number of saw-type teeth ensured full participation of all teeth in rock cutting, enabling efficient rock removal and maximizing breakage performance. Compared with other designs, this cutter exhibited the smallest fluctuations and mean cutting force. The specific mechanical energy decreased initially and then increased with the number of saw-type teeth, reaching a minimum for the four saw-type tooth design. Moreover, it showed the lowest surface temperature and the mildest temperature variation, which helps alleviate localized heating and improve wear resistance. The cutting performance of the four saw-type tooth was further influenced by cutting depth and back rake angle, with optimal values identified as 1.5 mm and 20°, respectively. Compared with a conventional cutter, the four saw-type tooth design reduced the overall surface temperature by approximately 10.69%, with temperature rise confined mainly to the grooves between adjacent saw-type teeth and no widespread thermal concentration observed, confirming its design superiority. Full-scale rock-breaking simulations demonstrated that the bit equipped with four saw-type tooth achieved greater penetration depth and required lower torque than the conventional design, indicating enhanced rock-breaking ability and higher drilling efficiency. In conclusion, the four saw-type tooth PDC cutter design offers a promising approach for developing high-performance drill bits and reducing drilling costs. Full article
(This article belongs to the Special Issue Advanced Approaches in Drilling Processes and Enhanced Oil Recovery)
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14 pages, 1119 KB  
Article
Assessment of Initial Wettability Effects on Smart Water Injection Efficiency in Carbonate Reservoirs
by Alireza Kazemi and Masoud Pedrampour
Processes 2025, 13(12), 3842; https://doi.org/10.3390/pr13123842 - 27 Nov 2025
Cited by 1 | Viewed by 891
Abstract
Carbonate reservoirs, which hold a significant portion of the world’s oil reserves, are particularly challenging for enhanced oil recovery (EOR) due to their predominantly oil-wet nature and low permeability. Smart water injection (a low-cost, environmentally friendly EOR method) has demonstrated potential to enhance [...] Read more.
Carbonate reservoirs, which hold a significant portion of the world’s oil reserves, are particularly challenging for enhanced oil recovery (EOR) due to their predominantly oil-wet nature and low permeability. Smart water injection (a low-cost, environmentally friendly EOR method) has demonstrated potential to enhance recovery by modifying rock wettability. While numerous studies have examined smart-water mechanisms, the specific role of initial wettability (including Swi and core preservation state) in controlling its efficiency remains insufficiently quantified. This study addresses this critical gap by systematically investigating how initial wettability affects oil recovery during smart water flooding in a Middle Eastern carbonate reservoir. Core flooding experiments were conducted using brines enriched with potential-determining ions (SO42−, Ca2+, Mg2+) under varying wettability conditions. These tests were performed under controlled initial wettability conditions (Swi and preservation state) to ensure consistent and representative comparison across brine types. Results reveal that initial rock wettability plays a pivotal role in dictating the extent of wettability alteration and oil displacement. In strong oil-wet samples, sulfate-enriched brines induced substantial wettability shifts, significantly enhancing recovery. Conversely, ion saturation effects were observed, limiting further improvement beyond a threshold. Quantitatively, spontaneous water-displacement tests on core 122 at ambient conditions yielded 8.1% of OOIP at Swi = 10%, approximately twice the recovery of the same core in a dry (Swi = 0%) condition. Under reservoir-temperature core-flooding, seawater increased oil recovery from 38.3 to 53.1% OOIP in sample 122 and from 42.2 to 54.1% OOIP in sample 188 relative to formation water, corresponding to incremental gains of about 10–15 percentage points. These findings highlight the critical role of initial wettability characterization in designing effective smart-water EOR strategies. Tailoring brine composition to reservoir-specific wettability conditions enabled recovery improvements of approximately 10–15 percentage points relative to formation water at reservoir temperature. The results provide clear mechanistic insight into ion-specific interactions and offer practical guidance for optimizing smart-water formulation and deployment in carbonate reservoirs. Full article
(This article belongs to the Special Issue Advanced Approaches in Drilling Processes and Enhanced Oil Recovery)
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