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Energies
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Methods of Increasing the Efficiency of Enhanced Oil Recovery
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Methods of Increasing the Efficiency of Enhanced Oil Recovery

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

Deadline for manuscript submissions: closed (21 October 2023) | Viewed by 3111

Special Issue Editors

Dr. Rasoul Mokhtari

E-Mail Website
Guest Editor
Danish Offshore Technology Centre, Technical University of Denmark, 2800 Kongens Lyngby, Denmark
Interests: fluid flow through porous media; carbon storage; enhanced oil recovery
Dr. Karen L. Feilberg

E-Mail Website
Guest Editor
Danish Hydrocarbon Research and Technology Centre, Technical University of Denmark, Copenhagen, Denmark
Interests: enhanced oil recovery; carbon storage petroleomics; interfacial phenomena; surface chemistry; analytical chemistry

Special Issue Information

Dear Colleagues,

There are many enhanced oil recovery methods with the potential to be applied in different fields depending on the physical and chemical condition of the reservoirs. Some of these methods—including traditional waterflooding or gas injection—are well described and widely implemented by the industry. There are, however, advanced methods to target inaccessible oil which cannot be recovered by conventional EOR methods. Technology to modify the composition, interfacial behavior, or otherwise design the chemical behavior of injection fluid has been a subject of great interest in both industry and academia in recent years due to the potential for incremental recovery improvements as well as environmental impact reduction. Many enhanced oil recovery techniques are still debated with respect to exact physicochemical mechanisms and recovery potential across different rock types and local conditions.
 
In this Special Issue, we invite contributions addressing novel findings in the methods of increasing the efficiency of EOR methods and their underlying mechanisms, including but not limited to:

  • Low/modified salinity water flooding; 
  • Chemical EOR;
  • Foam flooding;
  • Thermal EOR;
  • Microbial EOR;
  • Miscible/immiscible gas injection;
  • EOR methods in mature fields;
  • Novel EOR methods;
  • Any side effects during the implementation of EOR methods affecting their efficiency, such as organic and inorganic depositions.

In this Special Issue, we welcome papers investigating these research topics both in experiment and modeling approaches across different scales—from the molecular to the reservoir scale.

Dr. Rasoul Mokhtari
Dr. Karen L. Feilberg
Guest Editors

Dr. Rasoul Mokhtari
Dr. Karen L. Feilberg
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
  • porous media
  • rock–fluid–fluid interactions
  • environmental impact of oil production
  • experimental results
  • reservoir simulation
  • upscaling
  • optimization

Published Papers (2 papers)

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Research

19 pages, 21108 KiB  
Article
Assessing the Influence of Fracture Networks on Gas-Based Enhanced Oil Recovery Methods
by Riyaz Kharrat, Nouri Alalim and Holger Ott
Energies 2023, 16(17), 6364; https://doi.org/10.3390/en16176364 - 2 Sep 2023
Cited by 1 | Viewed by 946
Abstract
Numerous reservoirs that play a significant role in worldwide petroleum production and reserves contain fractures. Typically, the fractures must form a connected network for a reservoir to be classified as naturally fractured. Characterizing the reservoir with a focus on its fracture network is [...] Read more.
Numerous reservoirs that play a significant role in worldwide petroleum production and reserves contain fractures. Typically, the fractures must form a connected network for a reservoir to be classified as naturally fractured. Characterizing the reservoir with a focus on its fracture network is crucial for modeling and predicting production performance. To simplify the solution, dual-continuum modeling techniques are commonly employed. However, to use continuum-scale approaches, properties such as the average aperture, permeability, and matrix fracture interaction parameters must be assigned, making it necessary to improve the fracture depiction and modeling methods. This study investigated a fractured reservoir with a low matrix permeability and a well-connected fracture network. The focus was on the impact of the hierarchical fracture network on the production performance of gas-based enhanced oil recovery methods. The discrete fracture network (DFN) model was utilized to create comprehensive two-dimensional models for three processes: gas injection (GI), water alternating gas (WAG), and foam-assisted water alternating gas (FAWAG). Moreover, dimensionless numbers were employed to establish connections between properties across the entire fracture hierarchy, spanning from minor to major fractures and encompassing the fracture intensity. The results indicate that the FAWAG process was more sensitive to fracture types and networks than the WAG and GI processes. Hence, the sensitivity of the individual EOR method to the fracture network requires a respective depth of description of the fracture network. However, other factors, such as reservoir fluid properties and fracture properties, might influence the recovery when the minor fracture networks are excluded. This study determined that among the enhanced oil recovery (EOR) techniques examined, the significance of the hierarchical depth of fracture networks diminished as the ratio of major (primary fracture) aperture to the aperture of medium and minor fractures increased. Additionally, the impact of the assisted-gravity drainage method was greater with increased reservoir height; however, as the intensity ratio increased, the relative importance of the medium and minor fracture networks decreased. Full article
(This article belongs to the Special Issue Methods of Increasing the Efficiency of Enhanced Oil Recovery)
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21 pages, 6983 KiB  
Article
Impact of Gas Liberation Effects on the Performance of Low Permeability Reservoirs
by Nikolai Andrianov, Niels Marinus Bech, Carsten Møller Nielsen, Wael Al-Masri and Alexander Shapiro
Energies 2022, 15(10), 3707; https://doi.org/10.3390/en15103707 - 18 May 2022
Cited by 1 | Viewed by 1615
Abstract
Production from the North Sea reservoirs often results in a pressure decrease below the bubble point. The gas is liberated from oil, in the form of bubbles or as a continuous flowing phase. In such cases, the two phases, gas and oil, flow [...] Read more.
Production from the North Sea reservoirs often results in a pressure decrease below the bubble point. The gas is liberated from oil, in the form of bubbles or as a continuous flowing phase. In such cases, the two phases, gas and oil, flow in the reservoir simultaneously, and the flow is governed by the values of relative permeabilities. Traditional core flooding in low permeability rocks is challenging, therefore we use a novel experimental approach to determine the oil relative permeabilities below the critical gas saturation. A mathematical model has been created to reconstruct both the gas and the oil relative permeabilities for the whole saturation range. Laboratory observations have shown that in low-permeable rocks the relative permeabilities may strongly decrease, even when the amount of the liberated gas is small. The goal of this work is to verify, on a specific example, whether the designed model for the relative permeabilities may explain the observed production behavior for a low-permeable chalk reservoir in the North Sea. We perform a sensitivity study using the parameters of relative permeabilities and analyze the corresponding differences in well productivities. A reasonably good match of <10% can be obtained to the historical well production data. A few cases where the match was not satisfactory (14% to 65%) are also analyzed, and the difference is attributed to the imprecise fluid model. The developed experimental and modeling methodology may be applied to other reservoirs developed by the solution gas drive mechanism. Full article
(This article belongs to the Special Issue Methods of Increasing the Efficiency of Enhanced Oil Recovery)
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