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"PVT Analysis for Compositional Simulation" by Steve Furnival

In order to perform flow simulation in the reservoir and production system, we need to know various physical properties of the fluid system. Firstly, what phases are present? Gas? Oil? Water? What are the relative proportions of these phases? What are the bulk phase properties, i.e. density, viscosity, thermal conductivity, etc.

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• | •

Generally, the fluid composition within the production system is not fixed for a variety of reasons. Within the reservoir, the following changes can take place:

• Composition varies with depth and areal location. The presence of high permeability streaks can then allow different fluids to mix.

• As fluid drops below saturation pressure, one phase – generally the gas – will flow in preference to the oil so the produced well composition changes with time. This effect is particularly important for Gas Condensates and Volatile Oils – near critical fluids.

• Gas injection for pressure maintenance or miscibility processes.

Within the production system:

• Fluids from different parts of the reservoir or reservoirs, can mix, i.e. Eastern Trough Area Project (ETAP).

• Gas injection for Gas-Lift.

• Changes in surface separation.

• Phase slippage in long pipe and flow lines can cause formation of liquid slugs.

All these cases, and more, point to the need for a compositional treatment of the fluid system. These methods are computational expensive. However, with the rapid increase in computer power at reducing cost, they are all now achievable on a high-end PC.

TOC

1. Introduction

2. Hydrocarbon Composition

3. Phase Behaviour

4. Sampling and Laboratory Analysis

5. Equations of State

6. Flash Calculation

7. Characterization

8. Regression

9. Export for Simulation

References

Appendix A. Classical Thermodynamics

• A1 Abstractions

• A2 Chemical Potential

• A2.1 Fugacity

• A3 Equilibrium

• | •

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