Enhanced oil recovery application in low permeability formations by the injections of CO2, N2 and CO2/N2 mixture gases

Abstract

Low oil recovery which is very predominant in shale oil reservoirs has stimulated petroleum engineers to investigate the applications of enhanced oil recovery methods in these formations. One such application is the injection of gases into the formation to stimulate increased oil recovery. In many gas flooding projects performed in the field, the miscibility of the gas injected is usually the most desired displacement mechanism, and carbon dioxide (CO2) gas has been recognized to be the best performing gas for injection due to its ability to be miscible with oil in the reservoir at low pressures compared to other gases such as nitrogen. This minimum miscibility pressure (MMP) is of very crucial importance because it is the primary limiting factor in the feasibility of a miscible gas flooding project. However, there are other limiting factors such as cost and availability and, in these instances, nitrogen (N2) and lean gas are the more preferred candidate as opposed to carbon dioxide gas. Mixing carbon dioxide gas with lean gas or with nitrogen in a required ratio can allow us to design an injection gas that will be suitable enough to satisfy both the availability and cost constraints and at the same time allow us to achieve a reachable and reasonable miscibility pressure. The objective of this paper is to investigate the effect of mixing nitrogen gas and carbon dioxide gas in a 50:50 ratio on oil recovery in tight oil formations. The experiment was performed with controlled constraints such as the same core sample, same crude oil and same core cleaning and saturation process which was repeated for each trial. The oil used was live oil from Eagle ford formation, and the gases used were nitrogen (99.9% purity), carbon dioxide and a mixture of nitrogen and carbon dioxide in a 50:50 ratio. The injection pressure ranged from 1000 to 5000 psi with pressure increments of 1000 psi, and the same flooding time was 6 h. The potential of the N2, CO2 and N2–CO2 mixture for improving oil recovery was assessed along with the breakthrough time. The results showed that CO2 gas had the highest recovery followed by the N2–CO2 mixture and N2 gas had the lowest recovery. The gas breakthrough time results showed that the N2–CO2 mixture had the longest breakthrough time, N2 had the shortest breakthrough time, and CO2 had a significantly longer breakthrough time than pure N2 gas. The RF increased with increasing pressure, but the gas breakthrough time decreased with increasing pressure. However, the incremental RF decreased in all three cases when the injection pressure was above 3000 psi.

Asphaltene Precipitation and Deposition during Nitrogen Gas Cyclic Miscible and Immiscible Injection in Eagle Ford Shale and Its Impact on Oil Recovery

“…Higher pressure and longer soaking time led to higher oil recovery even beyond miscibility conditions for CO 2 . Bougre et al 77 conducted an experimental investigation to study the effect of flooding with CO 2 , N 2 and a CO 2 −N 2 mixture on oil recovery in tight formations. The same core sample was used in all experiments and saturated with live oil from the Eagle Ford formation.…”

Alterations of Carbonate Mineral Matrix and Kerogen Micro-Structure in Domanik Organic-Rich Shale during Anhydrous Pyrolysis

“…Firstly, despite no water being used in the experiment, water is still present in the Domanik Formation sample [72][73][74], and it can also be naturally generated during the thermal cracking of kerogen [75]. Secondly, a number of EOR shale-oriented techniques utilize gases, such as high-pressure air injection with further self-pyrolysis [76] and CO 2 or N 2 injection [77][78][79][80]. Thirdly, there are ex situ shale retorting techniques which use pyrolysis [81].…”

Studi Simulasi Reservoir pada Lapangan Shale Gas

“…Selain yang disebutkan di atas, Bougre et al (2021) [5] melakukan eksperimen coreflooding menggunakan N2, CO2, dan campuran N2 dan CO2 di suatu core dengan permeabilitas kecil dalam kondisi terkendali. Perlu diketahui bahwa meskipun fluida reservoir pada sampel core ini adalah fluida minyak, tinjauan pustaka ini diambil untuk melihat perilaku desorpsi suatu reservoir jika dilakukan injeksi.…”