Page 451 - Handbook Of Multiphase Flow Assurance

CHAPTER
12

Flow assurance modeling

Flow assurance model relies on system description including
• Reservoir characterization
• PVT fluid characterization
• Material characteristics
The sequence of flow assurance modeling in time follows the exploration process.
1. At the time of selection of region for exploration, find analog fluids to estimate
properties.
– Only analog fluids may be available for flow assurance study.
estimate density ±10°API.
estimate viscosity @ T_reservoir ±10 cP.
estimate wax appearance temperature ±20 °C.
estimate rock material and consolidation.
limited understanding about porosity, permeability, aquifer presence and strength,
water composition, GOR, hydrate, asphaltene, etc.
Appropriate flow assurance work at this stage: none.
What minimum work could be done:
– estimate hydrate curve based on guessed GOR and analog composition, using PVT
modeling tools.
– estimate scale tendency based on analog water composition.
– estimate wax appearance temperature based on analog fluid.
– estimate asphaltene tendency based on deBoer plot and/or SARA ratio.
– prepare a list of flow assurance laboratories and chemical supplier candidates.
2. By the time exploration well is in place.
– First fluids are available
Measure P_res, P_sat, GOR, density, viscosity, AOP, WAT, SARA;
Limited understanding about aquifer pressure support strength, reservoir
compartmentalization, water composition.
Basic understanding of wax, asphaltene onset pressure, GOR, hydrate conditions,
porosity, permeability, fines and sand from side core plugs.

Handbook of Multiphase Flow Assurance 451 © 2019 Elsevier Inc. All rights reserved.
https://doi.org/10.1016/B978-0-12-813062-9.00012-9