Simulasi Numerik Untuk Memprediksi Penurunan Temperatur Pada Lapangan Minyak Berat Di Lapangan DTW Dengan Pola Inverted 7-Spot

Primary depletion/waterflooding is often inefficient when used for the production of heavy oil reserves because it has a high viscosity. Steam injection can be used as a method for heavy oil production. The conventional method used to obtain a Temperature profile is by running a wireline log across the desired interval. A reservoir simulation was developed to find the correlation equation between changes in reservoir temperature and steam flood parameters. Equations are used as an alternative to patterns that do not have observation wells. Furthermore, the equation can be used to predict the decrease in reservoir temperatur without requiring observation well survey data. Simulations are carried out by histoy matching to the actual temperatur data in the DTW field. The simulation is limited to the scope of 1 injection pattern with an inverted 7-spot pattern. The first sand area is the main injection target with a production/injection time of 10 years from 2009 to 2019. The purpose of this paper is to simulate injection in the DTW field in 1 inverted 7-spot injection pattern to see the spread of steam and the rate of temperatur decline with time. In addition, it determines the correlation between the rate of temperatur reduction and the rate of steam injection and compares the heat mining tool with the results of the CMG simulator so that it can be seen whether the CMG results can be used as an alternative for DTW field managers. The method to achieve the goal is to collect data and perform data analysis using commercial simulation software CMG (Computer Modeling Group). The CMG model in this study is a close boundary model and to achieve a match on the field data, pseudo wells are added. Pseudo wells are made as oil injectors between wells 2 and 4 in the history matching stage for production. While at the historical matching steam rate stage, the addition of a pseudo well is made as a steam producer between wells 3 and 5 because it is assumed that the steam movement leads to that area because the area is higher than the area at wells 2 and 4. It can be seen that the steam injection rate affects the temperatur of reservoi