Benyamin Yadali Jamaloei

Detailed investigations into the production behavior of heavy oil reservoirs under foamy solution gas drive have been conducted extensively in the past. Historically, two approaches have been used to explain and model the solution gas drive in heavy oil reservoirs. The first approach is the base of foamy oil models in which solution gas drive is governed by parameters such as compressibility, viscosity, nonequilibrium phenomena, and the supersaturation. In the second approach, conventional modeling, which we show to be suitable for the history matching and prediction of the production data and macroscopic modeling of a series of depletion experiments (using a live combination of heavy oil and methane gas in a three-dimensional rectangular laboratory model), the foamy oil flow mechanism, dispersed flow of gas and the supersaturation are nonexistent. The conventional modeling uses parameters such as critical gas saturation, very low gas relative permeability, and the assumption of no supersaturation in the reservoir.

The significance of Joule-Thomson effect in petroleum industry applications has extensively been documented in the literature. In the first part of an extensive literature survey conducted on the significance of Joule-Thomson effect in petroleum fields Yadali Jamaloei and Asghari, 2015, this effect was presented in well testing, in multilateral/slanted wells, in drilling/completion/production operations, and in hydrate formation. In this article, the second part of this comprehensive review is presented, which consists of Joule-Thomson effect in CO₂ injection into depleted natural gas reservoirs, in prediction of wellbore temperature profiles, and the influence of thermal stresses resulting from this effect on the wellbore stability. It is expected that this article will serve as a reference tool for the engineers interested in the Joule-Thomson effect in petroleum fields.

This study examines the effect of pore geometry on the viscous instability in surfactant-polymer flooding in an initially preferential water-wet porous medium filled with heavy oil and brine. Two approaches are used to characterize the effect of viscous instability. In both approaches, the dynamic mean pore-scale capillary number is considered as the foremost criterion to characterize the effect of viscous instability. In the first approach, which is a pore network approach, the effect of viscous instability on is neglected. In the second approach, the viscous instability effect is included by using the viscous instability theory to determine . The comparison between from the port network approach and viscous instability theory is used to show the effect of viscous instability. The change in was found to be an appropriate tool to characterize the effect of viscous instability in surfactant-polymer flooding.

The significance of Joule-Thomson effect—occurring in throttling-type processes, such as adiabatic flow—in downstream and upstream petroleum industry applications cannot be overemphasized. In this article, the first part of a comprehensive review of this effect in oil and gas field applications is presented. For space reasons, the second part of the review will be presented in a second article. The first part of this review, which is the subject of the present work, includes the Joule-Thomson effect in well testing in oil and gas fields, in applications regarding the horizontal/multilateral/slanted wells, and in drilling, completion, production testing, and monitoring. In addition, challenges of the hydrate formation associated with Joule-Thomson cooling effect are discussed. It is expected that this article would serve as a helpful reference tool for the engineers interested in the Joule-Thomson effect in oil/gas field applications.

-Inondation chimique dans les réservoirs naturellement fracturés : aspects fondamentaux et pratiques de plein champ-Des méthodes appropriées devraient être utilisées pour augmenter la récupération d'huile des réservoirs naturellement fracturés (RNFs). Un des candidats pour augmenter cette récupération d'huile de ces réservoirs est l'injection d'eau contenant des agents chimiques. Cet article met en lumière les résultats techniques et les défis de cette technique. La classification, les caractéristiques de production, les mécanismes de rétablissement du RNFs et les résultats significatifs de l'injection d'eau contenant des agents chimiques dans ces réservoirs sont passés en revue et analysés. Ce papier vise à être un outil de référence utile aux ingénieurs intéressés par l'injection d'eau contenant des agents chimiques dans les RNFs. Abstract-Chemical Flooding in Naturally Fractured Reservoirs: Fundamental Aspects and Field-Scale Practices-Appropriate methods should be employed to enhance the oil recovery from the Naturally Fractured Reservoirs (NFRs). One of the candidates for enhancing the oil recovery from these reservoirs is the surfactant-based chemical flooding. This paper highlights the technical achievements and challenges of the chemical flooding in the NFRs. The classification, production characteristics, recovery mechanisms of the NFRs and significant findings of the chemical flooding in these reservoirs are reviewed and analyzed. It is expected that this paper will serve as a helpful reference tool for the engineers interested in chemical flooding in the NFRs.