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Energies
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Reservoir Simulation Studies for Enhanced Oil Recovery II
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Reservoir Simulation Studies for Enhanced Oil Recovery II

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

Deadline for manuscript submissions: closed (24 July 2024) | Viewed by 3213

Special Issue Editor

Prof. Dr. Mojdeh Delshad

E-Mail Website
Guest Editor
Hildebrand Department of Petroleum and Geosystems Engineering, The University of Texas at Austin, Austin, TX 78712, USA
Interests: geologic carbon storage; enhanced oil recovery; reservoir engineering; unconventional resources; reservoir simulation
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

We are soliciting high-quality technical papers for the Special Issue “Reservoir Simulation Studies for Enhanced Oil Recovery II”. Many EOR techniques have been evaluated in pilot studies and at commercial scales with three major processes of miscible gas and chemical and thermal methods. New hybrid EOR methods are currently under field testing to improve cost and recovery efficiencies, such as low salinity water/polymer, gas/surfactant (low tension foam), and CO2 storage in oil reservoirs, among others.

There has been growing motivation and contribution to EOR projects for improving reservoir characterization and process modeling for predicting recovery responses. Practically all EOR methods require a high-resolution description of the reservoir to capture the variations in reservoir properties more accurately. All EOR methods require specific correlations for phase behavior, fluid properties, and relative permeability/capillary pressure, among others. An understanding of the interactions of fluids/rock and the role of geochemistry in low salinity water, chemical, and CO2 floods have also been receiving increasing attention.

Prof. Dr. Mojdeh Delshad
Guest Editor

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Keywords

  • reservoir simulation
  • EOR methods
  • low salinity/smart water/designer water flood
  • polymer
  • surfactant/polymer
  • alkaline/surfactant/polymer
  • CO2 storage/utilization
  • hybrid EOR methods
  • shale oil EOR methods
  • laboratory/field scales
  • naturally fractured reservoirs
  • scale-up methodologies

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Published Papers (2 papers)

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Research

27 pages, 9657 KiB  
Article
Prospects of an Acid Gas Re-Injection Process into a Mature Reservoir
by Eirini Maria Kanakaki, Anna Samnioti, Evangelia Koffa, Irene Dimitrellou, Ivan Obetzanov, Yannis Tsiantis, Paschalia Kiomourtzi, Vassilis Gaganis and Sofia Stamataki
Energies 2023, 16(24), 7989; https://doi.org/10.3390/en16247989 - 9 Dec 2023
Cited by 3 | Viewed by 1326
Abstract
This study provides insights into the experience gained from the investigation of the dynamic behavior of a mature sour hydrocarbon reservoir modeling under an acid gas re-injection process production strategy. The primary objective was to analyze and evaluate the production behavior of proposed [...] Read more.
This study provides insights into the experience gained from the investigation of the dynamic behavior of a mature sour hydrocarbon reservoir modeling under an acid gas re-injection process production strategy. The primary objective was to analyze and evaluate the production behavior of proposed injection zones by assessing various injection scenarios and obtaining oil production over time. To achieve that, a workflow was developed to prioritize potential injection areas, select the optimal wells, determine the optimal operational parameters and optimize a pilot application design based on expected performance. Within this framework, the study encompasses diverse acid gas injection schemes on a pilot scale approach, including acid gas combined with waterflooding. The outcome of this analysis will eventually lead to the identification of the most promising and highest-performing injection scheme, elucidating the optimal range of operating parameters. This optimal combination forms the basis for the economic analysis of the venture and the subsequent detailed design of a full-scale application, where real-world implementation will validate the projected results. Full article
(This article belongs to the Special Issue Reservoir Simulation Studies for Enhanced Oil Recovery II)
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34 pages, 9639 KiB  
Article
A Systemic Comparison of Physical Models for Simulating Surfactant–Polymer Flooding
by Muhammad M. Alhotan, Bruno R. Batista Fernandes, Mojdeh Delshad and Kamy Sepehrnoori
Energies 2023, 16(15), 5702; https://doi.org/10.3390/en16155702 - 30 Jul 2023
Cited by 4 | Viewed by 1144
Abstract
Three different reservoir simulators that utilize both two-phase and three-phase microemulsion phase behavior models are used to model surfactant–polymer flooding to determine and compare their results. Different models are used in each simulator to describe the physical behavior of injected chemicals into the [...] Read more.
Three different reservoir simulators that utilize both two-phase and three-phase microemulsion phase behavior models are used to model surfactant–polymer flooding to determine and compare their results. Different models are used in each simulator to describe the physical behavior of injected chemicals into the reservoir, which raises the need to benchmark their results. The physical behavior models of polymer and surfactant were constructed and verified on a 1D scale reservoir model and further verified in a 3D model. Finally, simulations were conducted in a field-scale reservoir containing 680,400 grids, where results were compared and analyzed. The 1D and 3D model results suggest an excellent match between the different simulators in modeling surfactant–polymer floods. In the case of the field-scale model, the simulators matched in terms of oil recovery and total volumes produced and injected, while having similar reservoir pressure profiles but with significant discrepancies in terms of injected and produced chemicals. These results indicate that despite the differences in the calculated injected and produced chemicals due to the different models in the simulators, the effect of surfactant–polymer floods on oil recovery, total injected and produced fluids, and average pressure profiles can be comparably modeled in all of the three simulators. Full article
(This article belongs to the Special Issue Reservoir Simulation Studies for Enhanced Oil Recovery II)
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