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Gas Slippage in Two-Phase Flow and the Effect of Temperature

2001; Linguagem: Inglês

10.2523/68778-ms

Kewen Li, Roland N. Horne,

Drilling and Well Engineering

Gas Slippage in Two-Phase Flow and the Effect of Temperature Kewen Li; Kewen Li Stanford University Search for other works by this author on: This Site Google Scholar Roland N. Horne Roland N. Horne Stanford University Search for other works by this author on: This Site Google Scholar Paper presented at the SPE Western Regional Meeting, Bakersfield, California, March 2001. Paper Number: SPE-68778-MS https://doi.org/10.2118/68778-MS Published: March 26 2001 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Li, Kewen, and Roland N. Horne. "Gas Slippage in Two-Phase Flow and the Effect of Temperature." Paper presented at the SPE Western Regional Meeting, Bakersfield, California, March 2001. doi: https://doi.org/10.2118/68778-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Western Regional Meeting Search Advanced Search AbstractGas slippage in single-phase gas flow (Klinkenberg Effect) has been investigated extensively. Few papers, however, have been published on the gas slippage in gas-liquid two-phase flow. The gas relative permeabilities at water saturations close to the residual value have been found to be significantly greater than one in both nitrogen-water and steam-water flow through rocks. These values became less than one after the calculation was calibrated by taking the two-phase gas slip effect into consideration. The gas relative permeabilities have been measured at different mean pore pressures and the values of two-phase gas slip factor have been computed at different water saturations. The effects of temperature on both nitrogen and steam slip factors have also been studied and compared. These data have then been used to conduct a calibration in order to obtain intrinsic gas relative permeabilities that do not vary with the test pressures. It has been found from the present work that neglecting the two-phase gas slip effect may overestimate gas relative permeabilities. It is the intrinsic gas relative permeabilities instead of those measured at low test pressure that should be utilized in numerical simulation or other reservoir engineering calculation.IntroductionGas-liquid relative permeabilities are fundamental properties in reservoir engineering and numerical simulation. There may be significant effect of gas slippage in gas-liquid two-phase flow. However, few experimental data regarding the gas slip effect in two-phase flow have been published. If the slip effect is not considered correctly, the gas relative permeabilities will vary with test pressures and may be greater than one at some water saturations. On the other hand, little attention has been paid to the measurements of steam slip factor even in single-phase flow. Reliable data for steam flow is essential to the study of steam injection in heavy oil reservoirs or water injection in geothermal reservoirs where steam is produced.Rose1 conducted experimental measurements of gas relative permeabilities in both synthetic cores (Alundum filters) and natural sandstone cores. Rose1 reported that the gas slip factor of the sandstone cores decreased with the increase of the liquid (water) saturation. Fulton2 performed experiments on Pyrex cylindrical filters and also found that the gas slip factor decreased with the increase of the liquid (water) saturation in a range from 0 to about 30%. These experiments were not conducted at liquid saturations above 30%. Therefore, Estes and Fulton3 extended their experiments to liquid saturations over 30%, ranging from 0 to about 88% using Soltrol oil as the liquid phase; they found a similar phenomenon to that described by Rose1 and Fulton2.Although many researchers1–3, including Sampath and Keighin4, demonstrated the decrease of gas slip factor with the increase of liquid saturation, the reason for which is not readily apparent. Actually, the experimental data presented by these authors are contradictory to the Klinkenberg5 equation, which is expressed as follows: Equation (1)where kg is the gas permeability at a mean pressure, pm, and kg8 the intrinsic permeability of gas at an infinite pressure; c is a proportionality factor with an apparent value of slightly less than 1; ? is the mean free path of the gas and r the average radius of the capillaries. Keywords: reservoir, gas slippage, experiment, gas phase, gas slip factor, two-phase flow, flow in porous media, water saturation, steam slip factor, slip effect Subjects: Reservoir Fluid Dynamics, Flow in porous media This content is only available via PDF. 2001. Society of Petroleum Engineers You can access this article if you purchase or spend a download.