RESERVOIR CHARACTERIZATION OF GITA A AND GITA B, TALANG AKAR FORMATION, BANUWATI FIELD, SUNDA BASIN
Banuwati Field is one of gas producer fields in Sunda Basin. This field is still in early production phase, but gas production should be boosted to supply to PLN electric generator. In order to optimally develop the field, detailed understanding is needed on reservoir characterization of Gita A a...
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| Format: | Theses |
| Language: | Indonesia |
| Subjects: | |
| Online Access: | https://digilib.itb.ac.id/gdl/view/78469 |
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| Institution: | Institut Teknologi Bandung |
| Language: | Indonesia |
| Summary: | Banuwati Field is one of gas producer fields in Sunda Basin. This field is still in
early production phase, but gas production should be boosted to supply to PLN
electric generator. In order to optimally develop the field, detailed understanding is
needed on reservoir characterization of Gita A and Gita B sands which are the main
reservoir in Banuwati Gas Field. The effort will also be supported by newly drilled
well in the middle of the field.
Reservoir characterization has been done on Talang Akar Formation, focused on
Gita A and Gita B interval. Observation was started on core description to get facies
associations, these associations then connected to Gamma ray log pattern so that it
could be correlated to all wells. Furthermore, is the building of 3D facies association
model using depth structure and net reservoir thickness maps for Gita A and Gita B
intervals. Then, petrophysical models were realized using the base of facies
association model. Porosity model utilizes the ELAN analyses curves which already
has high similarity compared to core analyses values, distributed using a
geostatistical method called Sequential Gaussian Simulation. Permeability model
realized using transformation equations from porosity model. Relationship between
core porosity and permeability were built with the base of facies associations
interpretation.
In conclusion, Gita A and Gita B reservoirs were deposited on fluvio-deltaic
environment. Core and log data integration show each interval has bar and channel
facies associations. Channel sands has the best reservoir quality with mean porosity
and permeability values 22% and 640 mD respectively. Bar sands facies has mean
porosity and permeability values 16% and 28 mD respectively. |
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