Normalization & Denormalization " Field Average Relative Permeability Curve"

Normalization & Denormalization " Field Average Relative Permeability Curve"

Do you know how to get the field average relative permeability curve?

By normalizing cores relative permeability curves, before we delve into the calculations, let’s first understand what normalization is!

Normalization in data analysis is a technique used to adjust the values of numeric data in a dataset to a common scale. The primary goal is to ensure that the data is measured on the same scale, which can prevent bias and improve the accuracy and efficiency of the analysis.

One of its types is Min-Max Scaling: This method scales the data to a fixed range, usually 0 to 1, by subtracting the minimum value and dividing by the range of the data.

Why Normalize Relative Permeability?

Consistency Across Datasets: Different experiments or simulations might produce relative permeability curves with different scales “ different initial water and critical oil saturations ”. Normalization ensures these curves can be compared directly.

Calculation procedures:

Step 1: Calculate the normalized water saturation Sw*

Step 2: Calculate the normalized relative permeability for the oil phase at different water saturation.

Step 3: Normalize the relative permeability of the water phase by applying the following expression.

Step 4: Determine the average normalized relative permeability values for oil and water as a function of the normalized water saturation by select arbitrary values of Sw* and calculate the average of kro* and krw* by applying the following relationships:

Step 5: Determine the average saturation for oil and water “ Swc & Soc “ by applying the following relationship:

Step 6: The last step in this methodology involves denormalizing the average curve to reflect

actual reservoir and conditions of Swc and Soc.

Summary

Steps

• Normalizing each core
• Averaging normalized relative permeabilities
• Denormalized Average normalized relative permeabilities and assigned to different regions of the reservoir based on the existing critical fluid saturation for each reservoir region.