{"id":8029,"date":"2022-11-14T07:17:33","date_gmt":"2022-11-14T07:17:33","guid":{"rendered":"https:\/\/file.currentschoolnews.com\/?post_type=product&p=8029"},"modified":"2022-12-14T12:56:08","modified_gmt":"2022-12-14T12:56:08","slug":"effects-of-near-wellbore-and-reservoir-fluid-compositional-changes-on-condensate-banking","status":"publish","type":"product","link":"https:\/\/pastexamquestions.com\/product\/effects-of-near-wellbore-and-reservoir-fluid-compositional-changes-on-condensate-banking\/","title":{"rendered":"Effects of Near Wellbore and Reservoir Fluid Compositional Changes on Condensate Banking"},"content":{"rendered":"

– Effects of Near Wellbore and Reservoir Fluid Compositional Changes on Condensate Banking –<\/strong><\/span><\/p>\n

Download Effects of Near Wellbore and Reservoir Fluid Compositional Changes on Condensate Banking<\/strong><\/span>. Students who are writing their projects can get this material to aid their research work.<\/span><\/span><\/p>\n

Abstract<\/strong><\/h3>\n

Gas condensate reservoirs are initially discovered as single-phase gas reservoirs. As the reservoir is produced below the fluid dew-point pressure, an increase in condensate saturation in the near wellbore region occur which reduces the relative permeability to gas and in turn causes productivity impairment<\/p>\n

It is pertinent to predict condensate banking behavior accurately during a field\u2019s operational phase to avoid problems with a well\u2019s ability to attain production targets.<\/p>\n

This paper seeks to explore the effects of near wellbore and reservoir fluid compositional changes on condensate banking using Velocity Dependent Relative Permeability (VDRP).<\/p>\n

To achieve this, a PVT data for gas condensate reservoir from a field was used to build an input data file using Eclipse 300. A single-layer, radial, 3D reservoir model was used to investigate the effects of VDRP on productivity index, relative permeability to gas and condensate recovery.<\/p>\n

When Velocity Dependent Relative Permeability (VDRP) option was adopted for volume flow rate of 10Mscfpd, there was no change in the gas relative permeability and productivity index.<\/p>\n

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This was due to low flow rate. However, when the flow rate was increased to 1000Mscfpd and 2000Mscfpd, the gas relative permeability reduced only by 36.1% and 23.6% respectively while the Productivity Index reduced by 34.2% and 21.7% respectively.<\/p>\n

The positive effect of VDRP assisted these low values.<\/p>\n<\/div>\n<\/div>\n

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Introduction<\/strong><\/h3>\n

1.1 Background of the Study<\/strong><\/p>\n

Gas condensate reservoirs are typically discovered as single-phase gas reservoirs. During the production life of wells drilled in gas condensate reservoirs, the pressure declines near- isothermally from the reservoir boundary to the well.<\/p>\n

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If the well flowing bottom-hole pressure drops below the dew-point pressure, the condensate drops out of the gas and forms a bank of liquid around the well (Gringarten\u00a0et al.,\u00a0<\/em>2000; Hashemi\u00a0et al.,\u00a0<\/em>2006) which is mainly composed of intermediate and heavier hydrocarbon components.<\/p>\n

When the condensate drops out in the reservoir, at first, the condensate liquid will not flow until the accumulated condensate saturation exceeds the critical condensate saturation. This leads to a loss of valuable hydrocarbons because the condensate contains most of the heavy hydrocarbon components.<\/p>\n

Besides that, near the wellbore where the condensate bank appears, there will be a multiphase flow, so the gas relative permeability is reduced. The reduction of gas relative permeability due to the condensate bank is called condensate blocking (or condensate banking).<\/p>\n<\/div>\n<\/div>\n<\/div>\n<\/div>\n<\/div>\n<\/div>\n

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