Adjustment Of Differential Liberation Data To Separator Conditions

Abstract

The actual reservoir process is neither flash nor differential.

Thus, regardless of the testing procedure, some adjustment

needs to be made to the resultant data to approximate the fluid

behavior in the oil production process. The conventional

method of adjustment extrapolates to negative values of

solution gas-oil ratio and formation volume factor leads to

values less than one at low pressure. Both extrapolations do

not conform to the physical behavior. This is due to the fact

that the conventional approach does not observe that the oil

relative density at reservoir conditions is the same regardless

of the process.

This paper presents a new approach to the adjustment of

differential liberation data to separator conditions. This

approach is based on the fact that both flash and differential

data should give the same value for the oil relative density at

the reservoir conditions. This is achieved by correcting all the

properties, i.e. solution gas-oil ratio, formation volume factor,

gas relative density and oil relative density. The new method

overcomes the disadvantages and limitation of the

conventional approach. This method is tested on 400 PVT files

from all over the world and the result is consistent with

physical behavior. A sample calculation is presented to outline

the new method.

Introduction

The differential solution gas-oil ratio is not the same as the

flash solution gas-oil ratio as shown in Fig. 1. Similarly, the

differential and flash oil formation volume factors are not the

same as depicted in Fig. 2. Thus, regardless of the testing

procedures - flash or differential, some correction needs to be

made on the resultant data to approximate the fluid behavior in

the oil production process.

The oil that leaves the reservoir is flashed to the separator,

necessitating

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