Saturation-height functions based on unique flow units have been developed as part of an integrated petrophysical analysis of a gas field. Furthermore, coupling the saturation functions with appropriate relative permeability models has effectively quantified hydrocarbon saturation, classified producibility of intervals and defined critical water saturation. The results show that linking depositional and diagenetic rock fabric to flow units, and then linking the flow units to zones with similar core capillary pressure and relative permeability relationships, have enhanced the utility of the saturation models. The saturation-height functions provided more accurate water saturation in the study field, and they can potentially overcome uncertainties associated with log interpretation, using Archie or shaly sand models.

The saturation-height models were developed from core capillary pressure (Pc) data to calculate water saturation versus depth, which is independent of logs. The relative permeability models were obtained from special core analysis (SCAL). Consequently, the core-based saturation height functions can be useful in the calibration of log-based petrophysical models and, via relative permeability, can also be used to estimate water-gas-ratios and critical water saturation.

Capillary pressure and relative permeability curves from special core analysis studies were distributed into corresponding flow units, based on the calculated flow zone indicators. Saturation-height functions were then developed for each unit and used to calculate water saturation in the study field.

Coupled with hydraulic unit (HU)-based relative permeability curves, the saturation models may provide more comprehensive petrophysical interpretation in gas bearing formations as well as highlight potential differences in reservoir producibility.