RESERVOIR SIMULATION STUDY OF OPTIMUM DEVELOPMENT IN LAYER A ON X FIELD, SOUTH SUMATRA
Joko Pamungkas; Ferdi Latuan
Department of Petroleum Engineering, Faculty of Mineral Technology, UPN Veteran Yogyakarta, Jalan SWK 104 (Lingkar Utara), Condong Catur, 55283, Yogyakarta, Indonesia
Abstract
Layer A on the X field has been produced since September 2007 until December 2016. This layer consists of 9 wells with current status: 1 production well (natural flow), 5 shut-in wells, and 3 dry-hole wells. The original oil in place of this layer is 28.113 MMSTB. The production data shows that oil cumulative production of this layer is 1.066 MMSTB, which means that the current recovery factor is 3.79 %. This number is very small, and since there is a lot of hydrocarbon area that have not been produced, an integrated reservoir simulation study is done to determine the optimum scenario for this layer development. The study begins with data collecting and processing; model validation through initialization, history matching and PI matching; remaining reserve determination; and simulation of field development scenarios. There are 5 scenarios simulated and until January 2043; Base Case (production of 1 existing well) gives 2.53 MMSTB or 9 % RF; Scenario 1 (Base Case + 3 gas lift wells) gives 3.15 MMSTB or 11.21 % RF; Scenario 2 (Scenario 1 + 3 development wells) gives 6.49 MMSTB or 23.09 % RF; Scenario 3 (Scenario 1 + 6 development wells) gives 7.68 MMSTB or 27.32 % RF; and Scenario 4 (Scenario 1 + 9 development wells) gives 7.58 or 26.97 % RF. From the reservoir simulation result, the optimum development scenario for this layer is Scenario 3.
Keywords: reservoir simulation; field development; optimum scenario
Topic: Petroleum and Geothermal Engineering