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Journal of Porous Media
インパクトファクター: 1.49 5年インパクトファクター: 1.159 SJR: 0.43 SNIP: 0.671 CiteScore™: 1.58

ISSN 印刷: 1091-028X
ISSN オンライン: 1934-0508

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Journal of Porous Media

DOI: 10.1615/JPorMedia.2019028940
pages 279-298

DEVELOPMENT OF SCALING CRITERIA FOR WATERFLOODING AND IMMISCIBLE CO2 FLOODING IN TIGHT FORMATIONS

Deyue Zhou
Petroleum Systems Engineering, Faculty of Engineering and Applied Science, University of Regina, Regina, Saskatchewan, Canada, S4S 0A2
Daoyong Yang
Petroleum Systems Engineering, Faculty of Engineering and Applied Science, University of Regina, Regina, Saskatchewan, Canada, S4S 0A2
Xiaoyan Meng
Petroleum Systems Engineering, Faculty of Engineering and Applied Science, University of Regina, Regina, Saskatchewan, Canada, S4S 0A2

要約

Experimental studies on secondary and tertiary recovery processes in tight oil formations require a set of scaling criteria to scale them up to field dimension for either optimizing field production or designing displacement experiments. In this study, scaling criteria have been developed and validated to evaluate performance of waterflooding and immiscible CO2 flooding in tight formations by performing three-dimensional (3D) sandpacked displacements. Experimentally, waterflooding and immiscible CO2 flooding processes have been conducted with the 3D physical model, respectively. Continuous CO2 flooding results in a relatively low oil recovery with 33.8% of original-oil-in-place after 1.20 pore volume of CO2 injection. Theoretically, mathematical formulas have been developed for the corresponding processes on the basis of dimensional and inspectional analyses. Mass transfer from CO2 to oil by dissolution and diffusion has been considered in the inspectional analysis; for relaxation of the scaling criteria, gravitational force, viscous force, and dispersion and diffusion have been considered critical factors. The moderate water and CO2 injection rates (i.e., 2.0 cm3/min and 200.0 cm3/min for water and CO2, respectively) are ensured to result in a transverse diffusion-dominated flow, further simplifying the scaling group. The relaxed scaling group has been subsequently validated with the experimental measurements. Capillary force and geometric factors are found to be negligible when scaling up the 3D physical model to the prototype. There exists a reasonably good agreement between laboratory measurements and simulation results of a field production. By using the validated scaling criteria, displacement experiments in the 3D physical model can be properly designed to simulate waterflooding and immiscible CO2 injection in a targeted tight formation so as to design and optimize the field-scale exploitation processes.