<![CDATA[Accurate prediction of heavy crude oil viscosity supports reservoir engineering, production planning, and flow assurance. This study presents a rigorous comparative evaluation rather than a new machine-learning framework. The published dataset, derived from Kamel et al. and reproduced by Li et al., represents 28 Middle Eastern heavy crude-oil samples through 196 development measurements and 47 independent holdout measurements at 20–80 °C. The supplied workbook contains API gravity, temperature, C1, C2, C3, C4–C6, C7+, and viscosity, with a development viscosity range of 632.88–1267.65 cP; however, it does not include row-level oil or reservoir identifiers. Linear Regression, the Beggs–Robinson correlation, SVR, Random Forest, and Gradient Boosting were evaluated. Imputation, scaling, and hyperparameter selection were embedded in repeated nested cross-validation with five outer folds repeated twice and five inner folds. Final models were evaluated once on the untouched 47-record holdout, with bootstrap confidence intervals, corrected pairwise tests, residual diagnostics, and held-out permutation importance. Gradient Boosting achieved an internal R² of 0.99313 (95% CI: 0.99077–0.99549) and RMSE of 11.41 cP (10.03–12.80). On the independent holdout, it achieved R² = 0.99308 (bootstrap 95% CI: 0.98772–0.99637), RMSE = 8.43 cP, MAE = 6.64 cP, and MAPE = 0.78%. Corrected comparisons showed lower RMSE than Random Forest and SVR. Holdout diagnostics detected no statistically significant heteroscedasticity for Gradient Boosting, and extreme-value sensitivity produced similar performance. Temperature and C7+ were the dominant held-out predictors. These results are encouraging within the sampled domain, but the absent oil identifiers prevent group-disjoint validation, and no external reservoir dataset supports field-level generalization.]]>
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