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Validation of model predictions of pore-scale fluid distributions during two-phase flow

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Abstract
Pore-scale two-phase flow modeling is an important technology to study a rock's relative permeability behavior. To investigate if these models are predictive, the calculated pore-scale fluid distributions which determine the relative permeability need to be validated. In this work, we introduce a methodology to quantitatively compare models to experimental fluid distributions in flow experiments visualized with microcomputed tomography. First, we analyzed five repeated drainage-imbibition experiments on a single sample. In these experiments, the exact fluid distributions were not fully repeatable on a pore-by-pore basis, while the global properties of the fluid distribution were. Then two fractional flow experiments were used to validate a quasistatic pore network model. The model correctly predicted the fluid present in more than 75% of pores and throats in drainage and imbibition. To quantify what this means for the relevant global properties of the fluid distribution, we compare the mam flow paths and the connectivity across the different pore sizes in the modeled and experimental fluid distributions. These essential topology characteristics matched well for drainage simulations, but not for imbibition. This suggests that the pore-filling rules in the network model we used need to be improved to make reliable predictions of imbibition. The presented analysis illustrates the potential of our methodology to systematically and robustly test two-phase flow models to aid in model development and calibration.
Keywords
X-RAY MICROTOMOGRAPHY, MULTIPHASE FLOW, POROUS-MEDIA, CONTACT-ANGLE, RELATIVE PERMEABILITY, CAPILLARY-PRESSURE, RESERVOIR CONDITIONS, MICRO-TOMOGRAPHY, FINES MIGRATION, BEREA SANDSTONE

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MLA
Bultreys, Tom, et al. “Validation of Model Predictions of Pore-Scale Fluid Distributions during Two-Phase Flow.” PHYSICAL REVIEW E, vol. 97, no. 5, 2018.
APA
Bultreys, T., Lin, Q., Gao, Y., Raeini, A. Q., AlRatrout, A., Bijeljic, B., & Blunt, M. J. (2018). Validation of model predictions of pore-scale fluid distributions during two-phase flow. PHYSICAL REVIEW E, 97(5).
Chicago author-date
Bultreys, Tom, Qingyang Lin, Ying Gao, Ali Q Raeini, Ahmed AlRatrout, Branko Bijeljic, and Martin J Blunt. 2018. “Validation of Model Predictions of Pore-Scale Fluid Distributions during Two-Phase Flow.” PHYSICAL REVIEW E 97 (5).
Chicago author-date (all authors)
Bultreys, Tom, Qingyang Lin, Ying Gao, Ali Q Raeini, Ahmed AlRatrout, Branko Bijeljic, and Martin J Blunt. 2018. “Validation of Model Predictions of Pore-Scale Fluid Distributions during Two-Phase Flow.” PHYSICAL REVIEW E 97 (5).
Vancouver
1.
Bultreys T, Lin Q, Gao Y, Raeini AQ, AlRatrout A, Bijeljic B, et al. Validation of model predictions of pore-scale fluid distributions during two-phase flow. PHYSICAL REVIEW E. 2018;97(5).
IEEE
[1]
T. Bultreys et al., “Validation of model predictions of pore-scale fluid distributions during two-phase flow,” PHYSICAL REVIEW E, vol. 97, no. 5, 2018.
@article{8620618,
  abstract     = {Pore-scale two-phase flow modeling is an important technology to study a rock's relative permeability behavior. To investigate if these models are predictive, the calculated pore-scale fluid distributions which determine the relative permeability need to be validated. In this work, we introduce a methodology to quantitatively compare models to experimental fluid distributions in flow experiments visualized with microcomputed tomography. First, we analyzed five repeated drainage-imbibition experiments on a single sample. In these experiments, the exact fluid distributions were not fully repeatable on a pore-by-pore basis, while the global properties of the fluid distribution were. Then two fractional flow experiments were used to validate a quasistatic pore network model. The model correctly predicted the fluid present in more than 75% of pores and throats in drainage and imbibition. To quantify what this means for the relevant global properties of the fluid distribution, we compare the mam flow paths and the connectivity across the different pore sizes in the modeled and experimental fluid distributions. These essential topology characteristics matched well for drainage simulations, but not for imbibition. This suggests that the pore-filling rules in the network model we used need to be improved to make reliable predictions of imbibition. The presented analysis illustrates the potential of our methodology to systematically and robustly test two-phase flow models to aid in model development and calibration.},
  articleno    = {053104},
  author       = {Bultreys, Tom and Lin, Qingyang and Gao, Ying and Raeini, Ali Q and AlRatrout, Ahmed and Bijeljic, Branko and Blunt, Martin J},
  issn         = {2470-0045},
  journal      = {PHYSICAL REVIEW E},
  keywords     = {X-RAY MICROTOMOGRAPHY,MULTIPHASE FLOW,POROUS-MEDIA,CONTACT-ANGLE,RELATIVE PERMEABILITY,CAPILLARY-PRESSURE,RESERVOIR CONDITIONS,MICRO-TOMOGRAPHY,FINES MIGRATION,BEREA SANDSTONE},
  language     = {eng},
  number       = {5},
  pages        = {14},
  title        = {Validation of model predictions of pore-scale fluid distributions during two-phase flow},
  url          = {http://dx.doi.org/10.1103/physreve.97.053104},
  volume       = {97},
  year         = {2018},
}

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