Drilling, Completion and Well Engineering for the Natural Energy Resources Extraction, Storage and Sustainable Management, 2nd Edition

Topic Information

Dear Colleagues,

The key to successfully meeting the growing global energy demand and achieving energy transition in sustainable, environmentally, and socially acceptable manner, lies in the processes of drilling and well completion. These processes are integral to various aspects, including oil and gas exploration and extraction, geothermal energy harnessing, gas hydrate exploration, deep mining, subsea mining, and underground storage of CO₂, hydrogen, and excess renewable energy in the form of compressed air. While drilling and well completion technologies have rapidly advanced, particularly in the realm of oil and gas exploration and production, their progress in other domains such as underground hydrogen storage, geothermal energy, deep mining, and storing excess renewable energy as compressed air has been very limited. These technological advancements also, must not only deliver cost-effective and safe well construction and completion throughout a well's lifecycle but also ensure sustainable development that addresses economic, health, safety, and environmental (HSE) concerns and societal challenges.

With this perspective in mind, we are pleased to reintroduce the previously successful topic, “Drilling, Completion and Well Engineering for the Energy Resources Extraction, Storage and Sustainable Technology” within the purview of esteemed journals like Energies, Geosciences, Minerals, and Resources. We also welcome contributions related to CO₂ Capture, Storage, Utilization, and Sequestration (CCUS) and Natural Resource Extraction, Natural Hydrogen Exploration and Production, Underground Hydrogen Storage.

This topic aims to encompass multidisciplinary scholarly works that delve deeply into the scientific principles and mechanisms, addressing critical economic, social, and technical challenges, and exploring innovative ideas and concepts in the broader context of Drilling, Completion, and Well Engineering for Natural Energy Resource Extraction, Storage, and Sustainable Development and Management.

Topics of interest for publication in this topic include but are not limited to:

• Drilling and completion engineering.
• Drilling Automation, artificial intelligence, machine learning within the scope of drilling, completion, well engineering deployment, along with advancements in fibre optics and sensor technology, and the concept of smart well completion.
• Drilling and completion fluids including phenomena related to multiphase fluid flow and developments in drilling fluid and cementing technology.
• Geomechanics, and earth modelling, wellbore stability; Borehole Integrity
• Material engineering, encompassing composite materials and sustainable material solutions.
• Utilising computational fluid dynamics and advanced numerical techniques, as well as advanced optimisation techniques for the analysis, prediction, interpretation, characterisation, and optimization of drilling, completion and operation processes
• Coil tubing drilling and completion;
• HSE (Health, Safety, and Environment) and sustainability aspects associated with drilling, completion, maintenance, and operations.
• Well integrity, and development of regularity framework and compliance throughout drilling, completion, and injection, operations.
• Decommission, Repurposing of existing wells, and plug and abandonment (P&A) procedures
• Process safety during drilling, including well control and considerations related to human elements.
• Advanced drilling technologies.

Dr. Mofazzal Hossain
Dr. Hisham Khaled Ben Mahmud
Dr. Md Motiur Rahman
Topic Editors

Keywords

Participating Journals

Journal Name	Impact Factor	CiteScore	Launched Year	First Decision (median)	APC
Energies energies	3.2	7.3	2008	16.2 Days	CHF 2600	Submit
Geosciences geosciences	2.1	5.1	2011	23.4 Days	CHF 1800	Submit
Minerals minerals	2.2	4.4	2011	18.2 Days	CHF 2400	Submit
Resources resources	3.2	7.2	2012	24.6 Days	CHF 1600	Submit

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Published Papers (7 papers)

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20 pages, 4487 KiB  

Open AccessArticle

Coupled Productivity Prediction Model for Multi-Stage Fractured Horizontal Wells in Low-Permeability Reservoirs Considering Threshold Pressure Gradient and Stress Sensitivity

by Long Xiao, Ping Yue, Hongnan Yang, Wei Guo, Simin Qu, Hui Yao and Lingqiang Meng

Energies 2025, 18(14), 3654; https://doi.org/10.3390/en18143654 - 10 Jul 2025

Viewed by 225

Abstract

Multi-stage fractured horizontal wells (MSFHWs) represent a crucial development approach for low-permeability reservoirs, where accurate productivity prediction is essential for production operations. However, existing models suffer from limitations such as inadequate characterization of complex flow mechanisms within the reservoir or computational complexity. This [...] Read more.

Multi-stage fractured horizontal wells (MSFHWs) represent a crucial development approach for low-permeability reservoirs, where accurate productivity prediction is essential for production operations. However, existing models suffer from limitations such as inadequate characterization of complex flow mechanisms within the reservoir or computational complexity. This study subdivides the flow process into three segments: matrix, fracture, and wellbore. By employing discretization concepts, potential distribution theory, and the principle of potential superposition, a productivity prediction model tailored for MSFHWs in low-permeability reservoirs is established. Moreover, this model provides a clearer characterization of fluid seepage processes during horizontal well production, which aligns more closely with the actual production process. Validated against actual production data from an offshore oilfield and benchmarked against classical models, the proposed model demonstrates satisfactory accuracy and reliability. Sensitivity analysis reveals that a lower Threshold Pressure Gradient (TPG) corresponds to higher productivity; a production pressure differential of 10 MPa yields an average increase of 22.41 m³/d in overall daily oil production compared to 5 MPa, concurrently reducing the overall production decline rate by 26.59% on average. Larger stress-sensitive coefficients lead to reduced production, with the fracture stress-sensitive coefficient exerting a more significant influence; for an equivalent increment, the matrix stress-sensitive coefficient causes a production decrease of 1.92 m³/d (a 4.32% decline), while the fracture stress-sensitive coefficient results in a decrease of 4.87 m³/d (a 20.93% decline). Increased fracture half-length and number enhance production, with an initial productivity increase of 21.61% (gradually diminishing to 7.1%) for longer fracture half-lengths and 24.63% (gradually diminishing to 5.22%) for more fractures; optimal critical values exist for both parameters. Full article

(This article belongs to the Topic Drilling, Completion and Well Engineering for the Natural Energy Resources Extraction, Storage and Sustainable Management, 2nd Edition)

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24 pages, 4986 KiB  

Open AccessArticle

Research on Multi-Cycle Injection–Production Displacement Characteristics and Factors Influencing Storage Capacity in Oil Reservoir-Based Underground Gas Storage

by Yong Tang, Peng Zheng, Zhitao Tang, Minmao Cheng and Yong Wang

Energies 2025, 18(13), 3330; https://doi.org/10.3390/en18133330 - 25 Jun 2025

Viewed by 841

Abstract

In order to clarify the feasibility of constructing a gas storage reservoir through synergistic injection and production in the target reservoir, micro-displacement experiments and multi-cycle injection–production experiments were conducted. These experiments investigated the displacement characteristics and the factors affecting storage capacity during the [...] Read more.

In order to clarify the feasibility of constructing a gas storage reservoir through synergistic injection and production in the target reservoir, micro-displacement experiments and multi-cycle injection–production experiments were conducted. These experiments investigated the displacement characteristics and the factors affecting storage capacity during the multi-cycle injection–production process for converting the target reservoir into a gas storage facility. Microscopic displacement experiments have shown that the remaining oil is primarily distributed in the dead pores and tiny pores of the core in the form of micro-bead chains and films. The oil displacement efficiency of water flooding followed by gas flooding is 18.61% higher than that of gas flooding alone, indicating that the transition from water flooding to gas flooding can further reduce the liquid saturation and increase the storage capacity space by 2.17%. Single-tube long-core displacement experiments indicate that, during the collaborative construction of a gas storage facility, the overall oil displacement efficiency without a depletion process is approximately 24% higher than that with a depletion process. This suggests that depletion production is detrimental to enhancing oil recovery and expanding the capacity of the gas storage facility. During the cyclic injection–production stage, the crude oil recovery rate increases by 1% to 4%. As the number of cycles increases, the incremental oil displacement efficiency in each stage gradually decreases, and so does the increase in cumulative oil displacement efficiency. Better capacity expansion effects are achieved when gas is produced simultaneously from both ends. Parallel double-tube long-core displacement experiments demonstrate that, when the permeability is the same, the oil displacement efficiencies during the gas flooding stage and the cyclic injection–production stage are essentially identical. When there is a permeability contrast, the oil displacement efficiency of the high-permeability core is 9.56% higher than that of the low-permeability core. The ratio of the oil displacement efficiency between the high-permeability end and the low-permeability end is positively correlated with the permeability contrast; the greater the permeability contrast, the larger the ratio. The research findings can provide a reference for enhancing oil recovery and expanding the capacity of the target reservoir when it is converted into a gas storage facility. Full article

(This article belongs to the Topic Drilling, Completion and Well Engineering for the Natural Energy Resources Extraction, Storage and Sustainable Management, 2nd Edition)

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20 pages, 7697 KiB  

Open AccessArticle

Reinjection of Produced Water into Formations in Unconventional Gas Reservoirs

by Haosen Xing, Peng Zheng, Ping Yue and Yu Mu

Energies 2025, 18(12), 3149; https://doi.org/10.3390/en18123149 - 16 Jun 2025

Viewed by 538

Abstract

This paper provides a comprehensive analysis of gas field produced water from four perspectives: water sources, chemical composition, treatment methods, and application scenarios. It identifies critical challenges in current formation reinjection practices, including poor containment performance for injection layers, difficulties in optimal layer [...] Read more.

This paper provides a comprehensive analysis of gas field produced water from four perspectives: water sources, chemical composition, treatment methods, and application scenarios. It identifies critical challenges in current formation reinjection practices, including poor containment performance for injection layers, difficulties in optimal layer selection, and uncertainties in injection volume determination. To address these issues, systematic selection criteria for reinjection layers were established. Taking a depleted gas reservoir in the Ordos Basin as a case study, we conducted a geological analysis of candidate formations based on previous research findings. We set up three groups of schemes regarding injection wells, injection rate, and permeability inhomogeneity and studied reservoir reinjection water volume, reinjection formation pressure, reinjection waves and range, and reinjection safety using three-dimensional numerical simulation technology. Finally, we selected the preferred scheme of reinjection well location in consideration of permeability inhomogeneity, with a cumulative reinjection volume of 1554.3 × 10⁴ m³ and a change in reinjection formation pressure of 0~20 MPa. The pressure change in the upper overburden of the reinjection layer was kept within 3 MPa, a value consistent with actual historical reinjection data, confirming again the accuracy of this layer selection strategy and the aforementioned layer selection analysis and providing a basis for layer selection and reinjection safety for the assessment of recovered water reinjection in other unconventional gas reservoirs. Full article

(This article belongs to the Topic Drilling, Completion and Well Engineering for the Natural Energy Resources Extraction, Storage and Sustainable Management, 2nd Edition)

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12 pages, 5105 KiB  

Open AccessArticle

Application of Carbon-Isotope-Logging Technology in High-Temperature and High-Pressure Wells: A Case Study of the Ledong Gas Field in the Yinggehai Basin

by Heng Geng, Xiaojun Xin, Leli Cheng, Jiarong Su, Yitao Hu, Ting Song, Ruike Wang and Yongkang Li

Energies 2025, 18(7), 1728; https://doi.org/10.3390/en18071728 - 30 Mar 2025

Viewed by 346

Abstract

Carbon isotope logging technology can obtain timely and accurate hydrocarbon fluid and reservoir geological information and has great application potential in oil–gas body property analysis, the comprehensive study of source rocks, and fault-sealing evaluation. Since 2014, real-time methane isotope logging technology has been [...] Read more.

Carbon isotope logging technology can obtain timely and accurate hydrocarbon fluid and reservoir geological information and has great application potential in oil–gas body property analysis, the comprehensive study of source rocks, and fault-sealing evaluation. Since 2014, real-time methane isotope logging technology has been applied in the western South China Sea. Based on the on-site, real-time, continuous, and accurate detection of methane carbon isotopes, combined with the rapid comprehensive analysis and evaluation of logging gas measurement data, the application effect in ultra-high-temperature and high-pressure wells in the western South China Sea has been remarkable. Taking the Ledong 10 Area of Yinggehai Basin as an example, real-time carbon isotope logging data can be used to quickly identify gas origins, source rock maturity, and gas source type and help judge the sealing quality of overburdened mudstone caps. This knowledge can serve as a reference for ascertaining the popularity of isotope-logging technology in other areas. Full article

(This article belongs to the Topic Drilling, Completion and Well Engineering for the Natural Energy Resources Extraction, Storage and Sustainable Management, 2nd Edition)

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25 pages, 6470 KiB  

Open AccessArticle

Thermal Energy Storage and Recovery in Fractured Granite Reservoirs: Numerical Modeling and Efficiency Analysis

by Nima Gholizadeh Doonechaly, Théo Halter, Alexis Shakas, Mahmoud Hefny, Maren Brehme, Marian Hertrich and Domenico Giardini

Geosciences 2024, 14(12), 357; https://doi.org/10.3390/geosciences14120357 - 20 Dec 2024

Viewed by 1120

Abstract

Although Aquifer Thermal Energy Storage (ATES) systems are widely researched, Fractured Thermal Energy Storage (FTES) systems are comparatively underexplored. This study presents a detailed numerical model of a fractured granitic reservoir at the Bedretto underground laboratory in Switzerland, developed using COMSOL Multiphysics. Energy [...] Read more.

Although Aquifer Thermal Energy Storage (ATES) systems are widely researched, Fractured Thermal Energy Storage (FTES) systems are comparatively underexplored. This study presents a detailed numerical model of a fractured granitic reservoir at the Bedretto underground laboratory in Switzerland, developed using COMSOL Multiphysics. Energy efficiency was evaluated across different flow rates and well configurations, including single-well and doublet systems, as well as for two different temperatures, namely 60 °C and 120 °C. The doublet configuration at an injection temperature of 60 °C with a flow rate of 2 kg/s demonstrated the highest energy efficiency among the cases studied. Potential applications for the stored heat are discussed, with scenarios including district heating for the nearby village and greenhouse heating. The results show that although FTES is associated with unique challenges, it has significant potential as a reliable thermal energy storage method, particularly in regions without suitable aquifers. It can also be considered as a cost-effective and competitive approach for climate mitigation (assuming the system is solely powered by solar-PV). This study provides insights into the viability and optimization of FTES systems and highlights the role of fracture/fault properties in enhancing energy efficiency. Full article

(This article belongs to the Topic Drilling, Completion and Well Engineering for the Natural Energy Resources Extraction, Storage and Sustainable Management, 2nd Edition)

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12 pages, 5470 KiB  

Open AccessArticle

Experimental Study of Energy Design Optimization for Underwater Electrical Shockwave for Fracturing Applications

by Mohamed M. Awad, Ibrahim Eltaleb and Mohamed Y. Soliman

Geosciences 2024, 14(1), 24; https://doi.org/10.3390/geosciences14010024 - 17 Jan 2024

Cited by 1 | Viewed by 2059

Abstract

Underwater electrical shockwave can be used as a waterless, chemical-free, and environmentally friendly fracturing technique. A detailed experimental study was performed to develop a correlation between the optimum energy required to generate a shockwave that could be used in fracturing rock samples with [...] Read more.

Underwater electrical shockwave can be used as a waterless, chemical-free, and environmentally friendly fracturing technique. A detailed experimental study was performed to develop a correlation between the optimum energy required to generate a shockwave that could be used in fracturing rock samples with the wire weight and diameter as independent factors. In addition, the effect of the water volume on the Underwater Electrical Wire Explosion (UEWE) was investigated to quantify the effect of the wellbore fluid volume in the fracturing process. The effect of increasing the discharge energy on the current waveform rising rate, peak amplitude, and fracturing geometry was investigated. A baseline for implementing the shockwave fracturing method on cement and limestone samples was defined to be used in future work. The results show that the water volume has a significant effect on the results of the experiment. A correlation was developed that defined the optimum minimum energy required to burn a certain wire weight with consideration to the wire diameter. Using the optimum required energy or higher will increases the current peak amplitude with the same current waveform rise rate, which leads to higher energy deposition into the wire and prevents the premature breakdown of the wire. The generated shockwave was used to successfully fracture cement and limestone cubic samples. Full article

(This article belongs to the Topic Drilling, Completion and Well Engineering for the Natural Energy Resources Extraction, Storage and Sustainable Management, 2nd Edition)

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17 pages, 8718 KiB  

Open AccessArticle

Hydraulic Radial Drilling Using a Rotary Hydraulic Nozzle Aimed at Increasing the Exploitation of Deposits

by Przemyslaw Toczek, Rafal Wisniowski, Albert Zlotkowski and Wojciech Teper

Energies 2023, 16(23), 7867; https://doi.org/10.3390/en16237867 - 1 Dec 2023

Cited by 3 | Viewed by 1446

Abstract

The exploration and development of new hydrocarbon deposits face increasing challenges, primarily driven by the shift away from hydrocarbons towards renewable energy sources like shallow geothermal deposits, wind farms, and photovoltaics. This shift necessitates finding solutions that minimize environmental impact and enable increased [...] Read more.

The exploration and development of new hydrocarbon deposits face increasing challenges, primarily driven by the shift away from hydrocarbons towards renewable energy sources like shallow geothermal deposits, wind farms, and photovoltaics. This shift necessitates finding solutions that minimize environmental impact and enable increased energy extraction from existing or decommissioned fields and wells. This paper explores the possibility of excavating from potentially depleted fields, where a significant portion (up to 85%) of the reservoir’s resources remain unrecoverable due to low reservoir energy. To address this, secondary and tertiary exploitation methods are proposed involving the supply of external energy to increase the pressure in the reservoir layer, thereby enhancing resource exploitation. One of the suggested tertiary methods involves reaming the deposit with multiple small-diameter radial holes using a hydraulic drilling nozzle. The entire process comprises several key components, including the coiled tubing unit (CTU), high-pressure flexible hose, window drilling kit for casing pipe, kit for positioning the exit of the hydraulic drilling head from the casing pipe, anchor, and hydraulic drilling head attached to the end of the high-pressure flexible hose. This method aims to increase the contact between the reservoir layer and the wellbore, potentially leading to an increase in or initiation of exploitation in certain deposit scenarios. The described method presents an environmentally friendly approach, eliminating the need for drilling new boreholes and offering cost-effective access to resources in decommissioned deposits with insufficient reservoir energy for self-exploitation. The applicability of this method to extract methane from coalbed seams is also mentioned in this article. In a separate article, the authors detail the design of a hydraulic drilling nozzle specifically for reaming the reservoir layer. Full article

(This article belongs to the Topic Drilling, Completion and Well Engineering for the Natural Energy Resources Extraction, Storage and Sustainable Management, 2nd Edition)

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