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Enhanced Oil Recovery Processes Evaluation, Design and Implementation

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A special issue of Energies (ISSN 1996-1073). This special issue belongs to the section "H1: Petroleum Engineering".

Deadline for manuscript submissions: closed (20 March 2023) | Viewed by 9870

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Dr. Rafael E. Hincapie

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1. Institute of Subsurface Energy Systems, Clausthal University of Technology, 38678 Clausthal-Zellerfeld, Germany
2. OMV Exploration & Production GmbH, 1020 Wien, Austria
Interests: oil recovery mechanics; enhanced oil recovery (with focus in chemical and thermal), reservoir surveillance and characterization; fluid flow in porous media; microfluidics; fluid dynamics (theory, computation); rheology; innovation and technology management; business and management development; project management and technical management

Special Issue Information

Dear Colleagues,

The applications of enhanced oil recovery (EOR) processes remain an attractive option for field development at any stage of its lifetime. Various EOR processes have been studied over recent years, some with a clear business case, and others that have mainly stayed at the feasibility/R&D stage. Evaluations of EOR processes and their designs until implementation require multiple stages that include various disciplines.

At the design/feasibility stage, the flow of fluids through porous media is often analyzed by combining three evaluations, namely, microscale, macroscale, and mesoscale. Microscale includes evaluations performed in microfluidics or lab-on-a-chip systems. Macroscale refers to flooding experiments performed in core plugs (carbonates and sandstones), sand packs or glass beads. During mesoscale evaluations, four main models are used (found in the literature), namely, continuum models, capillary bundle models, pore-scale network modelling and numerical methods. Overall, these steps support most of the elements of a final investment decision, from a subsurface technical/risk point of view. One additional element is the surface evaluation and matters related to cost and design. This further includes pilot test implementation and monitoring to guarantee a profitable project. Hence, key technological advancements that could support the decision-making and optimization process are of high importance.

This Special Issue is expected to bring together contributions covering all phases of an EOR project, namely, research, planning, field implementation, and surveillance. Many EOR projects and evaluations have been performed in the last decade, proving that EOR methods still have significant momentum globally. There is value to be unlocked in every aspect of an EOR project. Although there are several EOR techniques available, the focus is suggested, but not limited to, some certain processes. The focus is based on the suitability and applicability of each process, possible synergies, and possible support for carbon-efficient reservoir management. We also encourage papers on machine learning and artificial intelligence applications in enhanced oil recovery.

Chemical EOR: polymer, alkali, nanoparticles, surfactant, microbial, solvent and foams;
Low-salinity water flooding, smart water, engineered water;
Thermal EOR: steam injection (cyclic or continuous), in situ combustion;
Immiscible/miscible gas injection (either hydrocarbon, CO₂, N₂.

Dr. Rafael E. Hincapie
Guest Editor

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Keywords

recovery mechanisms
fluid flow in porous media
advanced oil recovery technologies
machine learning in EOR
artificial intelligence in EOR

Published Papers (5 papers)

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Research

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16 pages, 3724 KiB

Open AccessArticle

Hybrid Machine Learning for Modeling the Relative Permeability Changes in Carbonate Reservoirs under Engineered Water Injection

by Leonardo Fonseca Reginato, Rafael dos Santos Gioria and Marcio Augusto Sampaio

Energies 2023, 16(13), 4849; https://doi.org/10.3390/en16134849 - 21 Jun 2023

Viewed by 982

Abstract

Advanced production methods utilize complex fluid iteration mechanisms to provide benefits in their implementation. However, modeling these effects with efficiency or accuracy is always a challenge. Machine Learning (ML) applications, which are fundamentally data-driven, can play a crucial role in this context. Therefore, in this study, we applied a Hybrid Machine Learning (HML) solution to predict petrophysical behaviors during Engineered Water Injection (EWI). This hybrid approach utilizes K-Means and Artificial Neural Network algorithms to predict petrophysical behaviors during EWI. In addition, we applied an optimization process to maximize the Net Present Value (NPV) of a case study, and the results demonstrate that the HML approach outperforms conventional methods by increasing oil production (7.3%) while decreasing the amount of water injected and produced (by 28% and 40%, respectively). Even when the injection price is higher, this method remains profitable. Therefore, our study highlights the potential benefits of utilizing HML solutions for predicting petrophysical behaviors during EWI. This approach can significantly improve the accuracy and efficiency of modeling advanced production methods, which may help the profitability of new and mature oil fields. Full article

(This article belongs to the Special Issue Enhanced Oil Recovery Processes Evaluation, Design and Implementation)

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26 pages, 6932 KiB

Open AccessArticle

Wellbore and Reservoir Thermodynamic Appraisal in Acid Gas Injection for EOR Operations

by Anna Samnioti, Eirini Maria Kanakaki, Evangelia Koffa, Irene Dimitrellou, Christos Tomos, Paschalia Kiomourtzi, Vassilis Gaganis and Sofia Stamataki

Energies 2023, 16(5), 2392; https://doi.org/10.3390/en16052392 - 2 Mar 2023

Cited by 5 | Viewed by 2046

Abstract

This study provides insights into the experience gained from investigating the thermodynamic behavior of well and reservoir fluids during acid gas injection (AGI) in a hydrocarbon field to enhance oil recovery (EOR) and to reduce greenhouse gas emissions. Unlike conventional water and natural gas injection, AGI involves complicated phase changes and physical property variations of the acid gas and reservoir fluids at various pressure-temperature (P-T) conditions and compositions, and both constitute crucial parts of the EOR chain. A workflow is developed to deal with the reservoir fluid and acid gas thermodynamics, which is a key requirement for a successful design and operation. The workflow focuses firstly on the development of the thermodynamic models (EoS) to simulate the behavior of the reservoir fluids and of the injected acid gas and their integration in the field and in well dynamic models. Subsequently, the workflow proposes the thermodynamic simulation of the fluids’ interaction to determine the Minimum Miscibility Pressure (MMP), yielding the dynamic evolution of the fluids’ miscibility that may appear within the reservoir. Flow assurance in the acid gas transportation lines and in the wellbore is also considered by estimating the hydrate formation conditions. Full article

(This article belongs to the Special Issue Enhanced Oil Recovery Processes Evaluation, Design and Implementation)

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21 pages, 2005 KiB

Open AccessArticle

Innovative Experimental Design for the Evaluation of Nanofluid-Based Solvent as a Hybrid Technology for Optimizing Cyclic Steam Stimulation Applications

by Hugo Alejandro García-Duarte, María Carolina Ruiz-Cañas and Romel Antonio Pérez-Romero

Energies 2023, 16(1), 373; https://doi.org/10.3390/en16010373 - 29 Dec 2022

Cited by 2 | Viewed by 1384

Abstract

Worldwide gas emissions are being strictly regulated, therefore processes to reduce steam injection for enhanced oil recovery (EOR) require a deeper analysis to identify the means to contribute to environmental impact reduction. Lately the usage of additives such as a solvent for steam injection processes has taken a new interest due to its positive impact on improving oil recovery and energy efficiency and reducing greenhouse gas emissions. In that sense, the use of nanoparticles in thermal EOR has been explored due to its impact on avoiding the volatilization of the solvent, offering greater contact with the oil in the reservoir. Nanoparticles have well-known effects on asphaltenes adsorption, aquathermolysis reactions, oil upgrading, and improving energy efficiencies. This article presents a summary and ranking of the nanoparticles evaluated in nanofluid-based solvent for steam processes, specifically in the catalysis of aquathermolysis reactions. A novel experimental design is proposed for the characterization, formulation (based on catalytic activity and dispersion), and evaluation of solvent improved with nanoparticles. This new approach will be used as a guideline for the evaluation of nanoparticles dispersed in hydrocarbon-type solvents as a hybrid technology to improve steam injection processes. Full article

(This article belongs to the Special Issue Enhanced Oil Recovery Processes Evaluation, Design and Implementation)

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50 pages, 9724 KiB

Open AccessFeature PaperArticle

Increasing Reservoir Recovery Efficiency through Laboratory-Proven Hybrid Smart Water-Assisted Foam (SWAF) Flooding in Carbonate Reservoirs

by Anas M. Hassan, Mohammed Ayoub, Mysara Eissa, Emad W. Al-Shalabi, Abdullah Al-Mansour and Abdulrahman Al-Quraishi

Energies 2022, 15(9), 3058; https://doi.org/10.3390/en15093058 - 22 Apr 2022

Cited by 11 | Viewed by 2470

Abstract

This contribution introduces a new hybrid enhanced oil recovery (EOR) method which combines smart water-assisted foam (SWAF) flooding, known as the SWAF process. The concept of applying SWAF flooding in carbonate reservoirs is a novel approach previously unexplored in the literature. The synergy effect of the SWAF technique has the potential to mitigate a number of limitations related to individual (i.e., conventional water injection and foam flooding) methods encountered in carbonates. In general, carbonate rocks are characterized by a mixed-wet to oil-wet wettability state, which contributes to poor oil recovery. Hence, the smart water solution has been designed to produce a dual-improvement effect of altering carbonate rock wettability towards more water-wet, which preconditions the reservoir and augments the stability of the foam lamellae, which has for some conditions more favorable relative permeability behavior. Then the smart water solution is combined with surfactant (surfactant aqueous solution or SAS) and gas injection produces a synergy effect, which leads to more wettability alteration, and interfacial tension (IFT) reduction, and thus improves the oil recovery. Accordingly, to determine the optimal conditions of smart water solution with an optimal SAS, we conducted a series of experimental laboratory studies. The experimental design is divided into three main steps. At first, the screening process is required so that the candidates can be narrowed down for our designed smart water using the contact angle tests that employ calcite plate (i.e., Indiana limestone or ILS) as the first filter. Following this, the optimum smart water solutions candidates are blended with different types of cationic and anionic surfactants to create optimum SAS formulations. Subsequently, a second screening process is performed with the aim to narrow down the SAS candidates with varying types of gases (i.e., carbon dioxide, CO

_{2}

and nitrogen, N

_{2}

) via the aqueous stability test (AST), foamability test (FT), and foam stability test (FST). We employed the state-of-the-art R5 parameter tests for rapid and accurate results in place of the conventional foam half-life method. The most effective combination of SAS and gas candidates are endorsed for the core-flooding experiments. In this work, two types of crude oils (Type A and B) with different total acid and base numbers (TAN and TBN). Results showed that the greatest wettability changes occurred for SW (MgCl

_{2}

) solution at 3500 (ppm) for both crude oil types. This demonstrates the efficacy of our designed SW in the wettability alteration of carbonates, which is also supported by the zeta-potential measurements. The concentrations of both SW (MgCl

_{2}

) and CTAB-based surfactants considerably affect the stability of the SAS (i.e., up to 90% foam stability). However when in the presence of crude oil, for the same SAS solution, the foam stability is reduced from 90% to 80%, which indicates the negative effect of crude oil on foam stability. Moreover, the core floods results showed that the MgCl

_{2}

-foam injection mixture (MgCl

_{2}

+ CTAB + AOS + N

_{2}

) provided the highest residual oil recovery factor of SWAF process of 92% cumulative recovery of original oil in core (OIIC). This showcases the effectiveness of our proposed SWAF technique in oil recovery from carbonate reservoirs. Additionally, changing the large slug of 5 PVs to a small slug of 2 PVs of smart water solution was more effective in producing higher OIIC recovery and in reducing the fluid circulation costs (i.e., thereby, lowering CO

_{2}

footprint), making the SWAF process environmentally benign. Thus, it is expected that under optimum conditions (SW solution and SAS), the novel SWAF process can be a potentially successful hybrid EOR method for carbonate reservoirs, having both economic and environmental benefits. Full article

(This article belongs to the Special Issue Enhanced Oil Recovery Processes Evaluation, Design and Implementation)

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26 pages, 6195 KiB

Open AccessEditor’s ChoiceReview

Recent Advances in the Study of In Situ Combustion for Enhanced Oil Recovery

by Andrey V. Minakov, Victoria D. Meshkova, Dmitry Viktorovich Guzey and Maksim I. Pryazhnikov

Energies 2023, 16(11), 4266; https://doi.org/10.3390/en16114266 - 23 May 2023

Cited by 5 | Viewed by 1950

Abstract

Global estimates for our remaining capacity to exploit developed oil fields indicate that the currently recoverable oil (light oil) will last for approximately 50 years. This necessitates the development of viscous and superviscous oil fields, which will further compensate for the loss of easily produced oil. In situ combustion is the most promising production method, which allows for increased oil recovery from a reservoir. This being the case, this study provides an overview of global trends regarding the research and implementation of the method under consideration, in order to promote understanding of its applicability and effectiveness. The background to the development of the method is discussed in detail, illustrating the growing interest of researchers in its study. Cases of both successful as well as inefficient implementations of this method in real oil fields are considered. The main focus of the article is to investigate the influence of the parent rock and catalysts on the combustion process, as this is a new and actively developing area in the study of enhanced oil recovery using in situ combustion. Geological surveys, in addition to experimental and numerical studies, are considered to be the main methods that are used to investigate processes during in situ combustion. The analysis that we carried out led us to understand that the processes which occur during the combustion of heavy oil are practically unpredictable and, therefore, poorly understood. The specificity of the oil composition under consideration depends on the field, which can lead to a change in the required temperature regimes for its production. This indicates that there exists multiple specific applications for the method under consideration, each requiring additional full studies into both the fractional composition of oil and its reservoirs. The article also considers various technologies for implementing the in situ combustion method, such as ND-ISC, THAITM, COSH, CAGD, and SAGD. However, the literature review has shown that none of the technologies presented is widely used, due to the lack of an evidence base for their successful application in the field. Moreover, it should be noted that this method has no limits associated with the oil occurrence depth. This technology can be implemented in thin reservoirs, as well as in flooded, clayey, sandy, and carbonate reservoirs. The review we have presented can be considered as a guide for further research into the development of global solutions for using the proposed method. Full article

(This article belongs to the Special Issue Enhanced Oil Recovery Processes Evaluation, Design and Implementation)

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