Open AccessNumerical study on enhancing coalbed methane recovery by injecting N 2 /CO 2 mixtures and its geological significance
Author(s) -
Fan Nan,
Wang Jiren,
Deng Cunbao,
Fan Yongpeng,
Mu Yongliang,
Wang Tingting
Publication year - 2020
Publication title -
energy science and engineering
Language(s) - English
Resource type - Journals
SCImago Journal Rank - 0.638
H-Index - 29
ISSN - 2050-0505
DOI - 10.1002/ese3.571
Subject(s) - coalbed methane , enhanced coal bed methane recovery , methane , permeability (electromagnetism) , coal , adsorption , petroleum engineering , carbon dioxide , desorption , ternary operation , natural gas , coal mining , chemistry , geology , biochemistry , organic chemistry , membrane , computer science , programming language
As an effective carbon utilization technology, the injection of N 2 /CO 2 mixtures into coal seams has significant potential for improving coalbed methane recovery. Considering the technical barrier that injection of pure CO 2 decreases the well injectivity index and pure N 2 injection leads to the rapid methane recovery, a method of injecting N 2 ‐enriched gas mixtures with a constant component is proposed. In this study, a thermo‐hydro‐mechanical (THM) coupling numerical model for enhanced coalbed methane (CBM) recovery by injecting N 2 /CO 2 mixtures is established. This model includes complex interactions of coal deformation, competitive adsorption, ternary gas seepage, and heat transfer. The THM coupling model is first validated, and then applied to investigate the evolution of mixed gas concentrations, reservoir permeability, reservoir temperature, CH 4 production, and N 2 /CO 2 storage during N 2 /CO 2 enhanced CBM recovery. The results show that the displacement radius and concentration of the mixed gas in the coal seam increased with gas injection pressure increase. The concentration of CH 4 gradually decreased with time, and the early decline is faster than the later stage. The sweep of the N 2 flow accelerates CH 4 desorption and migration, promoting a reduction in reservoir temperature near the production well. Reservoir permeability evolution results from the combined effects of ternary gases (CH 4 , CO 2 , N 2 ) competitive adsorption, gas pressure, and geostress on the coal seam within the THM fields. At the methane natural depletion stage (within 250 days), the permeability of coal reservoir first decreases and then increases. With the arrival of the N 2 /CO 2 mixture, the permeability decreases dramatically. From the perspective of cumulative CH 4 production, the optimal composition is dominated by the synergistic effect of maximizing breakthrough time and minimizing coal matrix swelling. For 30% CO 2 ‐70% N 2 , the CH 4 recovery ratio reached 71.76%, representing an increase of 16.67% compared to natural depletion.