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Energies
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Recent Advances in Oil and Gas Recovery and Production Optimisation
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Recent Advances in Oil and Gas Recovery and Production Optimisation

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

Deadline for manuscript submissions: 30 July 2024 | Viewed by 3169

Special Issue Editors

Dr. Gbenga Oluyemi

E-Mail Website
Guest Editor
School of Engineering, Robert Gordon University, Aberdeen AB10 7GJ, UK
Interests: oil and gas recovery; geomechanics; oil field chemistry; multiphase fluid; sand prediction and production; reservoir characterisation and simulation; value of information and asset management
Prof. Dr. Mamdud Hossain

E-Mail Website
Guest Editor
School of Engineering, Robert Gordon University, Gathdee Road, Aberdeen AB10 7GJ, UK
Interests: hydrogen and fuel cell; wave energy; multiphase flow induced vibration; separator design; computational fluid dynamics
Special Issues, Collections and Topics in MDPI journals
Dr. Richard O. Afolabi

E-Mail Website
Guest Editor
Petroleum Engineering Research Group (PERG), School of Engineering, Robert Gordon University, Aberdeen AB10 7GJ, UK
Interests: nanotechnology; transport in porous media; polymer enhanced recovery; production optimisation

Special Issue Information

Dear Colleagues,

Despite the current global drive towards energy transition and net zero energy to reduce greenhouse gas emissions, the demands for fossil-based energy continue to grow, partly due to the increasing global population, urbanisation, and industrialisation. A recent report by BP in 2019 confirmed that 85% of the global energy demand in 2018 was supplied by fossil-derived fuel. Therefore, it is expected that the contribution of fossil energy to the global energy demands would continue to increase, although it may be at a much slower rate than we have witnessed in the last few years. To meet the increasing demands for energy, the oil and gas industry needs to develop new methods and technologies that would enable more efficient production of hydrocarbon from the existing oil and gas fields.

The aim of this Special Issue is to disseminate the recent theoretical and applied research in oil and gas recovery and production optimisation covering reservoirs, wellbores, and topsides. The Special Issue will focus on exploring aspects such as reservoir management and monitoring, enhanced oil recovery, fluid technologies, formation damage mitigation, flow assurance, sand failure and production prediction, multiphase flow, and carbon capture and sequestration.

Dr. Gbenga Oluyemi
Prof. Dr. Mamdud Hossain
Dr. Richard O. Afolabi
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 100 words) can be sent to the Editorial Office for announcement on this website.

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

  • enhanced oil recovery
  • production optimisation
  • formation damage
  • well stimulation
  • flow assurance
  • geomechanics
  • sand transport

Published Papers (3 papers)

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Research

18 pages, 23684 KiB  
Article
Impact of Viscoelasticity on Sand-Carrying Ability of Viscous Slickwater and Its Sand-Carrying Threshold in Hydraulic Fractures
by Xianzhu Han, Junlin Wu, Yongjun Ji, Jinjun Liu, Yang Liu, Bobo Xie, Xianjiang Chen, Hui Yin and Tianbo Liang
Energies 2024, 17(2), 428; https://doi.org/10.3390/en17020428 - 16 Jan 2024
Viewed by 532
Abstract
Viscous slickwater has a higher viscosity and better sand-carrying ability than conventional slickwater at the same concentration. At a concentration of 0.4 wt.%, the viscosity of the viscous slickwater is 4.7 times that of the conventional slickwater. It is generally believed that viscosity [...] Read more.
Viscous slickwater has a higher viscosity and better sand-carrying ability than conventional slickwater at the same concentration. At a concentration of 0.4 wt.%, the viscosity of the viscous slickwater is 4.7 times that of the conventional slickwater. It is generally believed that viscosity is one of the main influencing factors on the sand-carrying ability of the fluid. However, this study has shown that the good sand-carrying ability of the viscous slickwater is more attributed to its viscoelasticity. Through rheology and sand-carrying tests, it has been found that the viscoelastic properties vary when fluids have the same viscosity; this then leads to a significant difference in the settling rate of sand and the sand-carrying threshold of the fluid in a fracture at a certain flow rate. The routine method of characterizing the viscoelastic property of the slickwater was to observe the cross point of the elastic modulus (G′) and viscous modulus (G″) curves. The smaller the frequency of the cross point, the better the viscoelastic property of the fluid. However, it has been found in experiments that even when the cross point is the same, there is still a significant difference in the sand-carrying ability of fluids. Therefore, sand-carrying experiments are conducted under a similar cross point and different magnitudes of modulus, of which the results indicate that as the elastic modulus increases, the settling rate of sand decreases. The flow rate threshold occurring as sand settles obtained from laboratory experiments is compared with the field condition during hydraulic fracturing. From laboratory experiments, the threshold of inner-fracture flow rate that prevents the sand settling is found to be 8.02 m/min for 0.6 wt.% viscous slickwater with a sand ratio of 30%. In the field operation, the operation conditions meet the sand-carrying threshold obtained from laboratory experiments. Observations from the field test confirm the applicability of the threshold plot proposed according to laboratory measurements, which can provide guidance for optimizing the fracturing scheme in the field. Full article
(This article belongs to the Special Issue Recent Advances in Oil and Gas Recovery and Production Optimisation)
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26 pages, 15639 KiB  
Article
Unconventional Reservoir Characterization and Formation Evaluation: A Case Study of a Tight Sandstone Reservoir in West Africa
by Amir Gharavi, Karrar A. Abbas, Mohamed G. Hassan, Malik Haddad, Hesam Ghoochaninejad, Reham Alasmar, Salam Al-Saegh, Paria Yousefi and Ihab Shigidi
Energies 2023, 16(22), 7572; https://doi.org/10.3390/en16227572 - 14 Nov 2023
Viewed by 1078
Abstract
Unconventional reservoirs, including gas shales and tight gas sands, have gained prominence in the energy sector due to technological advancements and escalating energy demands. The oil industry is eagerly refining techniques to decipher these reservoirs, aiming to reduce data collection costs and uncertainties [...] Read more.
Unconventional reservoirs, including gas shales and tight gas sands, have gained prominence in the energy sector due to technological advancements and escalating energy demands. The oil industry is eagerly refining techniques to decipher these reservoirs, aiming to reduce data collection costs and uncertainties in reserve estimations. Characteristically, tight reservoirs exhibit low matrix porosity and ultra-low permeability, necessitating artificial stimulation for enhanced production. The efficacy of the stimulation hinges on the organic material distribution, the rock’s mechanical attributes, and the prevailing stress field. Comprehensive petrophysical analysis, integrating standard and specialized logs, core analyses, and dynamic data, is pivotal for a nuanced understanding of these reservoirs. This ensures a reduction in prediction uncertainties, with parameters like shale volume, porosity, and permeability being vital. This article delves into an intricate petrophysical evaluation of the Nene field, a West African unconventional reservoir. It underscores the geological intricacies of the field, the pivotal role of data acquisition, and introduces avant-garde methodologies for depth matching, rock typing, and the estimation of permeability. This research highlights the significance of unconventional reservoir exploration in today’s energy milieu, offering a granular understanding of the Nene field’s geological challenges and proffering a blueprint for analogous future endeavours in unconventional reservoirs. Full article
(This article belongs to the Special Issue Recent Advances in Oil and Gas Recovery and Production Optimisation)
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25 pages, 8464 KiB  
Article
Hybrid Framework for Enhanced Dynamic Optimization of Intelligent Completion Design in Multilateral Wells with Multiple Types of Flow Control Devices
by Jamal Ahdeema, Morteza Haghighat Sefat and Khafiz Muradov
Energies 2023, 16(20), 7189; https://doi.org/10.3390/en16207189 - 21 Oct 2023
Viewed by 1131
Abstract
Multilateral wells (MLWs) equipped with multiple flow control devices (FCDs) are becoming increasingly favored within the oil sector due to their ability to enhance well-to-reservoir exposure and effectively handle unwanted fluid breakthrough. However, combining various types of FCDs in multilateral wells poses a [...] Read more.
Multilateral wells (MLWs) equipped with multiple flow control devices (FCDs) are becoming increasingly favored within the oil sector due to their ability to enhance well-to-reservoir exposure and effectively handle unwanted fluid breakthrough. However, combining various types of FCDs in multilateral wells poses a complex optimization problem with a large number of highly correlated control variables and a computationally expensive objective function. Consequently, standard optimization algorithms, including metaheuristic and gradient-based approaches, may struggle to identify an optimal solution within a limited computational resource. This paper introduces a novel hybrid optimization (HO) framework combining particle swarm optimization (PSO) and Simultaneous Perturbation Stochastic Approximation (SPSA). It is developed to efficiently optimize the completion design of MLWs with various FCDs while overcoming the individual limitations of each optimization algorithm. The proposed framework is further enhanced by employing surrogate modelling and global sensitivity analysis to identify critical parameters (i.e., highly sensitive) that greatly affect the objective function. This allows for a focused optimization effort on these key parameters, ultimately enhancing global optimization performance. The performance of the novel optimization framework is evaluated using the Olympus benchmark reservoir model. The model is developed by three intelligent dual-lateral wells, with inflow control devices (ICDs) installed within the laterals and interval control valves (ICVs) positioned at the lateral junctions. The results show that the proposed hybrid optimization framework outperforms all industry-standard optimization techniques, achieving a Net Present Value of approximately USD 1.94 billion within a limited simulation budget of 2500 simulation runs. This represents a substantial 26% NPV improvement compared to the open-hole case (USD 1.54 billion NPV). This improvement is attributed to more efficient water breakthrough management, leading to a notable 24% reduction in cumulative water production and, consequently, a 26% increase in cumulative oil production. Full article
(This article belongs to the Special Issue Recent Advances in Oil and Gas Recovery and Production Optimisation)
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