Reconciling the Modeled Log and Core Based Saturation Height Functions: A Case Study from a Gas-Condensate Reservoir.
- Suryanarayana Karri (Sproule) | Ernesto Pinto (Autoridade Nacional do Petróleo e Minerais) | Mateus da Costa (Autoridade Nacional do Petróleo e Minerais)
- Document ID
- Society of Petrophysicists and Well-Log Analysts
- SPWLA 60th Annual Logging Symposium, 15-19 June, The Woodlands, Texas, USA
- Publication Date
- Document Type
- Conference Paper
- 2019. held jointly by the Society of Petrophysicists and Well Log Analysts (SPWLA) and the submitting authors
- 3 in the last 30 days
- 127 since 2007
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Petrophysicists are adept at calculating water saturation using log data. Likewise, they are good at interpreting core measured capillary pressure data. In reservoir characterization, quite often, petrophysicists are required to transform the log derived water saturation or core based capillary pressure information into saturation height functions for a realistic representation of water saturation in 3D geomodels and simulation models.
If, for example, a field has only log data available the solution is straight-forward: generate saturation height functions using log derived water saturation. The situation gets complicated if the field has both log data and core based capillary pressure measurements. The dilemma is to decide which data to use. As consultants we come across varied data sets in both clastics and carbonate reservoirs all over the world. There are both commonalities and differentiators in these data sets when modelling water saturation. The solution to each problem could potentially be different. In our experience, there is no unique solution and the saturation height functions can be generated using log data entirely, using core data alone, or combining both data sets.
In other words, the outcome is reservoir and data specific as will be demonstrated with a case study from the Bayu-Undan gas condensate field in the Bonaparte Basin of the Northwest Shelf of Australia. Both data sets were available for this field and reconciling them to arrive at a realistic saturation height model is the key in this case. The intent is to emphasize that there is no universal preference. It is left to the discretion of the petrophysicists as to which path to take in order to generate the saturation height functions as realistically as possible.
In this case study, saturation height functions are generated for the purpose of static reservoir modeling of the Bayu-Undan gas-condensate reservoir. The field is in the Bonaparte Basin between Timor-Leste and the Northwest Shelf of Australia (Figure 1).
The structure is a broad east-west trending horst having several seismically recognisable internal faults (Figure 2).
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