| dc.description.abstract | The Norne field is located 80 km north of the Heidrun field in the Norwegian Sea. The Norne Field consists of two separate oil compartments, the Norne Main Structure (Norne C, D and E-Segment) and the Northeast Segment (Norne G-Segment). The Norne Main Structure was discovered in December 1991 and includes 97% of the oil in place. The Norne Main Structure contains sandstone reservoir rock Formations of Garn, Ile, Tofte, and Tilje Formations with the Norne E-Segment having 80% of the oil in place in the Ile and Tofte Formation which was produced from the year 1997 to 2006 when production was stopped. However, it was discovered that the Norne E-Segment Ile and Tofte Formations still contained a great percentage of producible oil and plans to resume production were initialized. In this study, reservoir simulation was performed using Grid dimensions and Grid cell properties, and well completion data combined with fluid and rock properties from Norne Field E-Segment using Eclipse Software version 2014 to identify alternative water flooding strategies, to determine the potential for surfactant flooding, and to determine the potential for polymer flooding in the Norne E-segment. Results show that water flooding with new producer well Z-3H and injectors F-1H, F-3H is the best water flooding optimum drainage strategy with recovery factor of 14% in the target Formation. Surfactant concentration of 0.6 kg/m3 gave the same oil production with less surfactant consumption compared to other concentrations, which were subjected to trials. Higher polymer concentrations correspond to the lower polymer production and oil production is higher for higher polymer concentrations. The highest oil production of 23 million Sm3 is achieved by the second water flooding scenario due to placement of a new producer well Z-3H in a good location of high oil saturation. Z-3H became the horizontal well in layer 9 hence recovers more oil. Since injection of surfactant slug led to the same oil recovery regardless of surfactant concentration because of the low saturation rate of the surfactant in the water. Higher polymer concentration diminishes the mobility ratio more by increasing the water viscosity resulting in a higher oil production.
This research shows that, water flooding with new producer well Z-3H and injectors F-1H, F-3H is the best water flooding optimum drainage strategy, different surfactant concentrations have the same oil production, and oil production is higher for higher polymer concentrations. | en_US |
