Near Critical Gas Condensate Relative Permeability of Carbonates

Abstract

Typical gas condensate fields contain a gas/liquid system during depletion. Such systems are difficult to model experimentally because they exhibit near-miscible behavior at high pressure and temperature. One way to simplify laboratory experimentation is to use a binary retrograde condensate fluid and to adjust temperature to control miscibility. A series of relative permeability test were conducted on a moderate-permeability carbonate core using methanol/n-hexane at near miscible conditions in the presence of immobile water. Potassium carbonate was added to the water to prevent miscibility with methanol. The experiments used a pseudo-steady-state technique under conditions similar to the near well region of a carbonate gas-condensate reservoir. The flow of gas and condensate at different force ratios was investigated. Relative permeabilities were obtained by matching historical production and pressure data using a coreflood simulator. It was observed that relative permeability depended on fluid composition and flow rate as well as initial condensate and water saturations. As the wetting phase (condensate) flow rate increased or interfacial tension decreased, relative permeability versus wetting phase saturation curves shifted towards lower wetting phase saturations. It was found that a simple three-parameter mathematical model that depends on a new dimensionless number called condensate number successfully modeled the gas-condensate relative permeability data. The developed model resulted in a good agreement with published gas-condensate relative permeability data as well as end point relative permeabilities and saturations. The relative permeability behavior as a function of IFT highly resembles the one observed in sandstones.

A proposed capillary number dependent model for prediction of relative permeability in gas condensate reservoirs: a robust non-linear regression analysis

“…In the current study, a cumulative of seven datasets were collected from the literature (Asar and Handy, 1988;Calisgan and Akin, 2008;Chen et al, 1995;Haniff and Ali, 1990;Henderson et al, 1997Henderson et al, , 1988Longeron, 1980) for developing a model for prediction of relative permeability in gas condensate reservoirs. A description of the aforesaid datasets including rock and fluid properties as well as the experiment methods (namely, steady-state and unsteadystate) is represented in Table 1.…”

“…The authors aimed advantages of simplicity and the least number of tuning parameters (constants)/variables integrated with averagely high reliability for various rock and fluid systems. To this end, regression analysis was carried out by employing seven sets of literature experimentally data (Asar and Handy, 1988;Calisgan and Akin, 2008;Chen et al, 1995;Haniff and Ali, 1990;Henderson et al, 1997Henderson et al, , 1988Longeron, 1980). The Capillary and Reynolds numbers were assessed to recognize the governing flow regime/forces over the utilized datasets.…”

“…A vast variety of data points from seven sets of literature published datasets (Asar and Handy, 1988;Calisgan and Akin, 2008;Chen et al, 1995;Haniff and Ali, 1990;Henderson et al, 1997Henderson et al, , 1988Longeron, 1980) were employed to develop a precise and reliable weighting function. To this end, regression analysis was carried out using Gauss-Newton and Levenberg-Marquardt algorithms.…”