Investigation of Temperature Effects on Oil-Water Relative Permeabilities for Small-Core Samples
Abstract/Contents
- Abstract
- Thermail oil recovery processes have resulted from interest in recovering viscous crudes. A knowledge of high temperature mutliphase flow in porous media is fundamental for understanding the effectiveness of such recovery processes. Relative permeability curves can aid in describing multiphase flow.Many studies have been directed towards the temperature effects on multiphase flow in porous systems. These studies have often resulted in contradictions.The original purpose of this study was to continue to work done on temperature effects on oil and water relative permeabilities of sands. The emphasis was to be with a consolidated system. The aim here would be to introduce greater heterogeneity into the system which would result in large variations in viscous and capillary forces within the porous medium. These variations may be more temperature sensitive and result in possible temperature effects no present in multiphase flow through unconsolidated porous media. During the preliminary study, it was determined that past work on the same apparatus was questionable. This study was then redirected: (a) to identify and explain the past inconsistencies obtained with the original apparatus, (b) to correct these difficulties, (c) to illustrate how experimental flow problems effect the measured relative permeability curves and define procedures that can be used to isolate errors in a complex system, and (d) to provide comparisons with long-core measurements and to represent guidelines for obtaining relative permeability measurements on small core samples.Obtaining an accurate method of measuring relative permeabilities on short cores is beneficial because most real reservoir cores are limited in sizeLaboratory dynamic: displacement relative permeability measurements were made on short unconsolidated sand packs in an attempt to isolate system problems. The fluids used were distilled water and refined-heavy mineral oil and refined-light mineral oil. Experiments were run on 1 in. diameter, 8in. long sand packs from room temperature to 150 degrees-F. A computer program was used to generate injectivity curves and relative permeability curves for a small-core system. Successful long-core measurements were used as a comparison.It is concluded that past results obtained with the original apparatus were affected by difficulties in determining material balance of fluids produced, inaccurate measurement of a constant flow rate and/or viscous instabilities
Description
| Type of resource | text |
|---|---|
| Date created | April 1983 |
Creators/Contributors
| Author | Roark, Rebecca Ann |
|---|---|
| Primary advisor | Brigham, William E. |
| Degree granting institution | Stanford University, Department of Petroleum Engineering |
Subjects
| Subject | School of Earth Energy & Environmental Sciences |
|---|---|
| Genre | Thesis |
Bibliographic information
Access conditions
- Use and reproduction
- User agrees that, where applicable, content will not be used to identify or to otherwise infringe the privacy or confidentiality rights of individuals. Content distributed via the Stanford Digital Repository may be subject to additional license and use restrictions applied by the depositor.
Preferred citation
- Preferred Citation
- Roark, Rebecca Ann. (1983). Investigation of Temperature Effects on Oil-Water Relative Permeabilities for Small-Core Samples. Stanford Digital Repository. Available at: https://purl.stanford.edu/ss184nh6941
Collection
Master's Theses, Doerr School of Sustainability
View other items in this collection in SearchWorksContact information
- Contact
- brannerlibrary@stanford.edu
Also listed in
Loading usage metrics...