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Effects of Near Wellbore and Reservoir Fluid Compositional Changes on Condensate Banking

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– Effects of Near Wellbore and Reservoir Fluid Compositional Changes on Condensate Banking –

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Abstract

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

It is pertinent to predict condensate banking behavior accurately during a field’s operational phase to avoid problems with a well’s ability to attain production targets.

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

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.

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.

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.

The positive effect of VDRP assisted these low values.

Introduction

1.1 Background of the Study

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.

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 et al., 2000; Hashemi et al., 2006) which is mainly composed of intermediate and heavier hydrocarbon components.

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.

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).

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