Imperial College London

ProfessorMatthewJackson

Faculty of EngineeringDepartment of Earth Science & Engineering

TOTAL Chair in Geological Fluid Mechanics
 
 
 
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Contact

 

+44 (0)20 7594 6538m.d.jackson

 
 
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Location

 

1.34Royal School of MinesSouth Kensington Campus

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Summary

 

Publications

Citation

BibTex format

@article{Debbabi:2018:10.1016/j.petrol.2017.11.063,
author = {Debbabi, Y and Stern, D and Hampson, GJ and Jackson, MD and Debbabi, Y and Stern, D and Hampson, GJ and Jackson, MD},
doi = {10.1016/j.petrol.2017.11.063},
journal = {Journal of Petroleum Science and Engineering},
pages = {270--282},
title = {Use of dimensionless scaling groups to interpret reservoir simulation results},
url = {http://dx.doi.org/10.1016/j.petrol.2017.11.063},
volume = {163},
year = {2018}
}

RIS format (EndNote, RefMan)

TY  - JOUR
AB - In conducting studies to make reservoir management decisions, it is important to efficiently interpret results of reservoir simulations. An understanding of how and why predicted reservoir performance changes with model parameters guides evaluation of production strategies as well as exploration of the impact of uncertainty in reservoir description. The aim of this work is to demonstrate the use of dimensionless scaling groups to interpret and qualitatively predict simulation results of multiphase flow in subsurface reservoirs with a large number of wells. Dimensionless scaling groups which quantify the balance between the forces causing fluid flow were computed between well pairs to rationalize simulation results. The data required to partition the model according to injector-producer pairs and estimate the scaling groups were obtained within minutes using simplified, single-phase numerical experiments. We show that scaling groups can be used to classify multiphase flow behaviours observed over the field into a small set of flow regimes characterized by the combination of their dominant forces. Changes in fluid distribution and reservoir performance with the model parameters can be analyzed in terms of changes in the force balance, and qualitatively predicted using the scaling groups. Predictions made using scaling groups may guide, and thereby reduce the use of, time-consuming multiphase flow simulations to optimize field development plans, to improve the calibration of reservoir models to production data and interpreted subsurface heterogeneity, and to assess the impact of reservoir uncertainties on production.
AU - Debbabi,Y
AU - Stern,D
AU - Hampson,GJ
AU - Jackson,MD
AU - Debbabi,Y
AU - Stern,D
AU - Hampson,GJ
AU - Jackson,MD
DO - 10.1016/j.petrol.2017.11.063
EP - 282
PY - 2018///
SN - 1873-4715
SP - 270
TI - Use of dimensionless scaling groups to interpret reservoir simulation results
T2 - Journal of Petroleum Science and Engineering
UR - http://dx.doi.org/10.1016/j.petrol.2017.11.063
UR - http://hdl.handle.net/10044/1/54369
VL - 163
ER -