AI-driven foam rheological model based on HPHT foam rheometer experiments

Zeeshan Tariq, Ahmed BinGhanim, Murtada Saleh Aljawad, Muhammad Shahzad Kamal, Mohamad Mahmoud, Zuhair AlYousef

Research output: Contribution to journalArticlepeer-review

3 Scopus citations

Abstract

Foam has many applications in the oil and gas industry, either in hydraulic fracturing, enhanced oil recovery, or drilling operations. The success of these operations depends largely on understanding the behavior of foam rheology, which is complex. The literature contains many models used to estimate the effective bulk foam viscosity; most were based on fitting parameters estimated from limited-experimental data. Nevertheless, the fitting parameters are not valid at different operating conditions such as temperature, pressure, and shear rate. This results in models with limited applicability as the laboratory conditions are hardly replicated. In this study, we generated 360 data points of effective bulk foam viscosity using the high pressure high temperature (HPHT) foam rheometer device. A wide range of conditions was examined, such as temperature, pressure, shear rate, foam quality, and composition. The gas-phase consisted of either CO2 or N2, while four types of water representing different salinities were used in the liquid phase. The foam was generated using seven different commercial surfactants at different concentrations. Also, low pH chelating agent and corrosion inhibitor were added in some experiments. The data pool was analyzed using four machine learning techniques: Artificial Neural Network (ANN), Decision Trees (DT), Random Forest Regressor (RFR), and K-Nearest Neighbor (KNN). ANN showed the highest accuracy with R2 of 0.972 and 0.985 on the training and testing datasets, respectively. Also, the relative importance of features was examined using Pearson, Spearman, and Kendall correlation coefficients. The most significant parameters in reducing foam viscosity were temperature, corrosion inhibitor, and shear rate, respectively. On the contrary, foam quality positively impacted the foam viscosity, where 80% foam quality was the maximum tested condition. The impact of pressure, surfactant concentration, water type, and chelating agents were complex. This paper provides a simplified ANN-based model which can be used on the fly to predict the effective bulk foam viscosity in both laboratory and field conditions.
Original languageEnglish (US)
Pages (from-to)110439
JournalJournal of Petroleum Science and Engineering
Volume213
DOIs
StatePublished - Mar 24 2022

Bibliographical note

KAUST Repository Item: Exported on 2022-07-06
Acknowledgements: The authors would like to thank the College of Petroleum Engineering & Geoscience, King Fahd University of Petroleum & Minerals for providing support to conduct this research.

ASJC Scopus subject areas

  • Geotechnical Engineering and Engineering Geology
  • Fuel Technology

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