Document Type : Regular Article

Authors

• Tamo Sop Berthelot ¹
• Tsapla Fotsa Rolande ²
• Tokoue Ngatcha Dianorré ³
• Kemnang Tsafack Alex Stephane ⁴
• Komofor Ngopuh Finalise ⁵
• Ngueuteu Mbouna Serge Gervais ⁶

¹ Department of Petroleum and Gas Engineering, School of Geology and Mining Engineering, University of Ngaoundere, P.O. BOX 115, Meiganga, Cameroon

² Department of Mechanical Engineering, College of Technology, University of Buea, P. O. Box: 63 Buea, Cameroon

³ Department of Automotive and Mechatronics Engineering, National Higher Polytechnic School of Douala, University of Douala, P.O. Box 24, 2701, Douala, Cameroon

⁴ Research unit of Condensed matter of electronics and signal processing. Dept. of Physics, Faculty of Science, University of Dschang, P.O. Box 67, Dschang, Cameroon

⁵ Department of Physics, Faculty of Science, University of Bamenda, P.O. Box 39 Bamenda, Cameroon

⁶ Laboratory of Modelling and Simulation in Engineering, Biomimetics and Prototypes, Faculty of Science, University of Yaoundé I, P.O. 812, Yaoundé, Cameroon

Abstract

The Gullfaks field constitutes one of the largest hydrocarbon deposits in Norway. It is divided into several geological formations: Cook, Statfjord, Lunde and the Brent group. It’s consists of several reservoirs, two of which are the subject of this paper: Tarbert and Ness reservior. This paper aim to re-pressurize the reservoir of the Gullfaks field through the implementation of a secondary oil recovery method by flooding the reservoir with water. Many methods have been employed for the estimation of hydrocarbons and the enhancement of oil recovery (EOR). This study utilises the water flooding method to optimized oil recovery in the Gullfak field. Based on data from the Gullfaks field provided by company X for security reason, a 3-dimension static model of the reservoir, created using Petrel, revealed a volume of 459 119 496,855 bbls of oil and 206 274 915 000 cf of gas. Subsequently, a 3-dimension dynamic model was constructed through Eclipse simulation to predict a 20-year operation (2000-2020) of water injection into the reservoir over 20 years (2000-2020). The results indicated an oil recovery factor of 28.8%, representing a 19.7% increase over the primary recovery of 9.1%. Similarly, the gas recovery factor was determined to be 36.1%, representing a 24.6% increase over the primary recovery of 11.5%. This exponential increase in gas and oil production has led to economic growth, indicating that this method enhanced high quality production in comparison to other oil recovery techniques.

Keywords

• Modeling
• simulation
• re-pressurize
• Petrel
• Gullfaks